10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)

☒ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended September 30, 2023

or

☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

Commission File No. 001-03262

COMSTOCK RESOURCES, INC.

(Exact name of registrant as specified in its charter)

Nevada	94-1667468
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification Number)

5300 Town and Country Blvd., Suite 500, Frisco, Texas 75034

(Address of principal executive offices)

Telephone No.: (972) 668-8800

Securities registered pursuant to Section 12(b) of the Act:

Title of each class	Trading Symbol(s)	Name of each exchange on which registered
Common Stock, par value $0.50 (per share)	CRK	New York Stock Exchange

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.

Yes ☒ No ☐

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).

Yes ☒ No ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of "large accelerated filer," "accelerated filer", "smaller reporting company" and "emerging growth company" in Rule 12b-2 of the Exchange Act. (Check one):

Large accelerated filer ☒	Accelerated filer ☐	Non-accelerated ☐	Smaller reporting company ☐
Emerging growth company ☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

Yes ☐ No ☒

The number of shares outstanding of the registrant's common stock, par value $0.50, as of November 1, 2023 was 278,429,463.

COMSTOCK RESOURCES, INC.

QUARTERLY REPORT

For the Quarter Ended September 30, 2023

INDEX

	Page
PART I. Financial Information
Item 1. Financial Statements (Unaudited):
Consolidated Balance Sheets as of September 30, 2023 and December 31, 2022	4
Consolidated Statements of Operations – for the three months and nine months ended September 30, 2023 and 2022	5
Consolidated Statements of Stockholders' Equity – for the three months and nine months ended September 30, 2023 and 2022	6
Consolidated Statements of Cash Flows – for the nine months ended September 30, 2023 and 2022	7
Notes to Consolidated Financial Statements	8
Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations	19
Item 3. Quantitative and Qualitative Disclosure About Market Risk	23
Item 4. Controls and Procedures	24
PART II. Other Information
Item 1A. Risk Factors	25
Item 5. Other Information	25
Item 6. Exhibits	25

2

PART 1 — FINANCIAL INFORMATION

ITEM 1. FINANCIAL STATEMENTS (UNAUDITED)

3

COMSTOCK RESOURCES, INC.

CONSOLIDATED BALANCE SHEETS

	As of
	September 30, 2023			December 31, 2022
	(Unaudited)
	(In thousands)
ASSETS
Cash and cash equivalents	$	19,835		$	54,652
Accounts receivable:
Natural gas and oil sales and gas services		157,130			415,079
Joint interest operations		36,506			76,521
From affiliates		21,168			18,527
Derivative financial instruments		23,973			23,884
Other current assets		68,572			56,324
Total current assets		327,184			644,987
Property and equipment:
Natural gas and oil properties, successful efforts method:
Proved		6,810,440			5,843,409
Unproved		323,666			298,230
Other		48,273			26,475
Accumulated depreciation, depletion and amortization		(1,962,418	)		(1,545,459	)
Net property and equipment		5,219,961			4,622,655
Goodwill		335,897			335,897
Operating lease right-of-use assets		148,066			90,716
	$	6,031,108		$	5,694,255
LIABILITIES AND STOCKHOLDERS' EQUITY
Accounts payable	$	503,564		$	530,195
Accrued costs		103,666			183,111
Operating leases		52,731			38,411
Derivative financial instruments		—			4,420
Total current liabilities		659,961			756,137
Long-term debt		2,503,407			2,152,571
Deferred income taxes		454,612			425,734
Derivative financial instruments		4,540			—
Long-term operating leases		95,397			52,385
Reserve for future abandonment costs		30,434			29,114
Total liabilities		3,748,351			3,415,941
Commitments and contingencies
Stockholders' equity:
Common stock—$0.50 par, 400,000,000 shares authorized, 278,429,463 and 277,517,087 shares issued and outstanding at September 30, 2023 and December 31, 2022, respectively		139,214			138,759
Additional paid-in capital		1,258,069			1,253,417
Accumulated earnings		885,474			886,138
Total stockholders' equity		2,282,757			2,278,314
	$	6,031,108		$	5,694,255

The accompanying notes are an integral part of these statements.

4

COMSTOCK RESOURCES, INC.

CONSOLIDATED STATEMENTS OF OPERATIONS

(Unaudited)

	Three Months Ended September 30,						Nine Months Ended September 30,
	2023			2022			2023			2022
	(In thousands, except per share amounts)
Revenues:
Natural gas sales	$	304,141		$	994,979		$	911,065		$	2,376,774
Oil sales		1,309			1,936			4,111			6,324
Total natural gas and oil sales		305,450			996,915			915,176			2,383,098
Gas services		71,287			193,090			239,350			322,575
Total revenues		376,737			1,190,005			1,154,526			2,705,673
Operating expenses:
Production and ad valorem taxes		25,386			24,531			59,891			60,080
Gathering and transportation		47,012			44,740			137,981			113,797
Lease operating		31,664			28,608			100,525			79,873
Exploration		—			—			1,775			3,363
Depreciation, depletion and amortization		148,190			129,065			422,350			354,994
Gas services		67,632			181,818			224,317			305,271
General and administrative		9,586			10,165			31,992			27,451
Loss (gain) on sale of assets		—			—			(125	)		(21	)
Total operating expenses		329,470			418,927			978,706			944,808
Operating income		47,267			771,078			175,820			1,760,865
Other income (expenses)
Gain (loss) from derivative financial instruments		14,276			(271,335	)		76,190			(781,654	)
Other income		409			56			1,467			506
Interest expense		(43,624	)		(41,393	)		(121,082	)		(132,204	)
Loss on early retirement of debt		—			—			—			(46,840	)
Total other expenses		(28,939	)		(312,672	)		(43,425	)		(960,192	)
Income before income taxes		18,328			458,406			132,395			800,673
Provision for income taxes		(3,608	)		(102,810	)		(28,878	)		(179,610	)
Net income		14,720			355,596			103,517			621,063
Preferred stock dividends		—			(4,411	)		—			(13,089	)
Net income available to common stockholders	$	14,720		$	351,185		$	103,517		$	607,974
Net income per share:
Basic	$	0.05		$	1.50		$	0.37		$	2.61
Diluted	$	0.05		$	1.28		$	0.37		$	2.24
Weighted average shares outstanding:
Basic		276,999			232,482			276,741			232,170
Diluted		276,999			277,715			276,741			277,605
Dividends per share	$	0.125		$	—		$	0.375		$	—

The accompanying notes are an integral part of these statements.

5

COMSTOCK RESOURCES, INC.

CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY

(Unaudited)

	Common Shares			Common Stock- Par Value			Additional Paid-in Capital			Accumulated Earnings (Deficit)			Total
	(In thousands)
Balance at January 1, 2022		232,925		$	116,462		$	1,100,359		$	(204,042	)	$	1,012,779
Stock-based compensation		(5	)		(2	)		1,479			—			1,477
Net loss		—			—			—			(111,424	)		(111,424	)
Payment of preferred stock dividends		—			—			—			(4,315	)		(4,315	)
Balance at March 31, 2022		232,920		$	116,460		$	1,101,838		$	(319,781	)	$	898,517
Stock-based compensation		239			119			115			—			234
Net income		—			—			—			376,891			376,891
Payment of preferred stock dividends		—			—			—			(4,363	)		(4,363	)
Balance at June 30, 2022		233,159		$	116,579		$	1,101,953		$	52,747		$	1,271,279
Stock-based compensation		599			300			(3,348	)		—			(3,048	)
Net income		—			—			—			355,596			355,596
Payment of preferred stock dividends		—			—			—			(4,411	)		(4,411	)
Balance at September 30, 2022		233,758		$	116,879		$	1,098,605		$	403,932		$	1,619,416
Balance at January 1, 2023		277,517		$	138,759		$	1,253,417		$	886,138		$	2,278,314
Stock-based compensation		(7	)		(4	)		2,050			—			2,046
Net income		—			—			—			134,503			134,503
Payment of common stock dividends		—			—			—			(34,688	)		(34,688	)
Balance at March 31, 2023		277,510		$	138,755		$	1,255,467		$	985,953		$	2,380,175
Stock-based compensation		983			491			(85	)		—			406
Net loss		—			—			—			(45,706	)		(45,706	)
Payment of common stock dividends		—			—			—			(34,689	)		(34,689	)
Balance at June 30, 2023		278,493		$	139,246		$	1,255,382		$	905,558		$	2,300,186
Stock-based compensation		(63	)		(32	)		2,687			—			2,655
Net income		—			—			—			14,720			14,720
Payment of common stock dividends		—			—			—			(34,804	)		(34,804	)
Balance at September 30, 2023		278,430		$	139,214		$	1,258,069		$	885,474		$	2,282,757

The accompanying notes are an integral part of these statements.

6

COMSTOCK RESOURCES, INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS

(Unaudited)

	Nine Months Ended September 30,
	2023			2022
	(In thousands)
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income	$	103,517		$	621,063
Adjustments to reconcile net income to net cash provided by operating activities:
Deferred income taxes		28,878			148,389
Gain on sale of assets		(125	)		(21	)
Depreciation, depletion and amortization		422,350			354,994
(Gain) loss on derivative financial instruments		(76,190	)		781,654
Cash settlements of derivative financial instruments		76,221			(679,038	)
Amortization of debt discount and issuance costs		5,980			8,542
Stock-based compensation		7,006			4,918
Loss on early retirement of debt		—			46,840
(Increase) decrease in accounts receivable		295,323			(359,600	)
(Increase) decrease in other current assets		(624	)		359
Increase (decrease) in accounts payable and accrued expenses		(73,697	)		301,956
Net cash provided by operating activities		788,639			1,230,056
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital expenditures and acquisitions		(1,088,933	)		(768,148	)
Prepaid drilling costs		(14,594	)		(25,752	)
Proceeds from sales of assets		41,295			93
Net cash used for investing activities		(1,062,232	)		(793,807	)
CASH FLOWS FROM FINANCING ACTIVITIES:
Borrowings on bank credit facility		575,000			705,000
Repayments of bank credit facility		(230,000	)		(840,000	)
Retirement of Senior Notes		—			(273,920	)
Preferred stock dividends paid		—			(13,089	)
Common stock dividends paid		(104,181	)		—
Debt and stock issuance costs		(144	)		—
Income tax withholdings on equity awards		(1,899	)		(6,255	)
Net cash provided by (used for) financing activities		238,776			(428,264	)
Net increase (decrease) in cash and cash equivalents		(34,817	)		7,985
Cash and cash equivalents, beginning of period		54,652			30,663
Cash and cash equivalents, end of period	$	19,835		$	38,648

The accompanying notes are an integral part of these statements.

7

COMSTOCK RESOURCES, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

September 30, 2023

(Unaudited)

(1) SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Basis of Presentation

These unaudited consolidated financial statements include the accounts of Comstock Resources, Inc. and its wholly-owned subsidiaries (collectively, "Comstock" or the "Company"). In management's opinion, the accompanying unaudited consolidated financial statements contain all adjustments necessary to present fairly the financial position of Comstock as of September 30, 2023, and the related results of operations and cash flows for the periods being presented. Net income and comprehensive income are the same in all periods presented. All adjustments are of a normal recurring nature unless otherwise disclosed.

The accompanying unaudited consolidated financial statements have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission. Certain information and disclosures normally included in annual financial statements prepared in accordance with accounting principles generally accepted in the United States have been omitted pursuant to those rules and regulations, although Comstock believes that the disclosures made are adequate to make the information presented not misleading. These unaudited consolidated financial statements should be read in conjunction with the financial statements and notes thereto included in Comstock's Annual Report on Form 10-K for the year ended December 31, 2022. The results of operations for the period through September 30, 2023 are not necessarily an indication of the results expected for the full year.

Other Current Assets

Other current assets at September 30, 2023 and December 31, 2022 consisted of the following:

	As of
	September 30, 2023		December 31, 2022
	(In thousands)
Pipe and well equipment inventory	$	50,708	$	34,819
Production tax refunds receivable		14,988		11,156
Prepaid expenses		2,876		2,455
Prepaid drilling costs		—		4,265
Accrued proceeds from sale of natural gas and oil properties		—		3,118
Other		—		511
	$	68,572	$	56,324

Property and Equipment

The Company follows the successful efforts method of accounting for its natural gas and oil properties. Costs incurred to acquire natural gas and oil leases and to drill and complete developmental wells are capitalized.

8

COMSTOCK RESOURCES, INC.

Exploratory well costs are initially capitalized as proved property in the consolidated balance sheets but charged to exploration expense if and when the well is determined not to have found commercial proved natural gas and oil reserves. The changes in capitalized exploratory well costs are as follows:

	Three Months Ended September 30,					Nine Months Ended September 30,
	2023			2022		2023			2022
	(In thousands)
Beginning capitalized exploratory well costs	$	34,196		$	9,771	$	867		$	6,966
Additions to exploratory well costs pending the determination of proved reserves		74,737			20,144		179,049			50,541
Determined to have found proved reserves		(71,838	)		—		(142,821	)		(27,592	)
Ending capitalized exploratory well costs	$	37,095		$	29,915	$	37,095		$	29,915

As of September 30, 2023 and December 31, 2022, the Company had no exploratory wells for which costs have been capitalized for a period greater than one year.

The Company assesses the need for an impairment of the capitalized costs for its proved natural gas and oil properties on a property basis. No impairments were recognized to adjust the carrying value of the Company's proved natural gas and oil properties during any of the periods presented. Unproved natural gas and oil properties are also periodically assessed and any impairment in value is charged to expense. The costs related to unproved properties are transferred to proved natural gas and oil properties and amortized on an equivalent unit-of-production basis when they are reflected in proved natural gas and oil reserves.

The Company determines the fair values of its natural gas and oil properties using a discounted cash flow model and proved and risk-adjusted probable natural gas and oil reserves. Undrilled acreage can also be valued based on sales transactions in comparable areas. Significant Level 3 assumptions associated with the calculation of discounted future cash flows included in the cash flow model include management's outlook for natural gas and oil prices, production costs, capital expenditures, and future production as well as estimated proved natural gas and oil reserves and risk-adjusted probable natural gas and oil reserves. Management's natural gas and oil price outlook is developed based on third-party longer-term price forecasts as of each measurement date. The expected future net cash flows are discounted using an appropriate discount rate in determining a property's fair value.

It is reasonably possible that the Company's estimates of undiscounted future net cash flows attributable to its natural gas and oil properties may change in the future. The primary factors that may affect estimates of future cash flows include future adjustments, both positive and negative, to proved and appropriate risk-adjusted probable natural gas and oil reserves, results of future drilling activities, future prices for natural gas and oil, and increases or decreases in production and capital costs. As a result of these changes, there may be future impairments in the carrying values of these or other properties.

Goodwill

The Company had goodwill of $335.9 million as of September 30, 2023 that was recorded in 2018. The Company is not required to amortize goodwill as a charge to earnings; however, the Company is required to conduct an annual review of goodwill for impairment. The Company performs an annual assessment of goodwill on October 1 of each year and performs interim assessments if indicators of impairment are present. If the carrying value of goodwill exceeds the fair value, an impairment charge would be recorded for the difference between fair value and carrying value.

Leases

The Company has right-of-use lease assets of $148.1 million related to its corporate office, certain office equipment, vehicles, drilling rigs and hydraulic fracturing fleets with corresponding short-term and long-term liabilities. The value of the lease assets and liabilities are determined based upon discounted future minimum cash flows contained within each of the respective contracts. The Company determines if contracts contain a lease at inception of the contract. To the extent that contract terms representing a lease are identified, leases are identified as being either an operating lease or a finance-type lease. Comstock currently has no finance-type leases. Right-of-use lease assets representing the Company's right to use an underlying asset for the lease term and the related lease liabilities represent our obligation to make lease payments under the terms of the contracts. Short-term leases that have an initial term of one year or less are not capitalized; however, amounts paid for those leases are included as part of its lease cost disclosures. Short-term lease costs exclude expenses related to leases with a lease term of one month or less. Leases for the right to explore for and develop natural gas and oil reserves and the related rights to use the land associated with those leases are reflected as natural gas and oil properties.

9

COMSTOCK RESOURCES, INC.

Comstock contracts for a variety of equipment used in its natural gas and oil exploration and development activities. Contract terms for this equipment vary broadly, including the contract duration, pricing, scope of services included along with the equipment, cancellation terms, and rights of substitution, among others. The Company's drilling and completion operations routinely change due to changes in commodity prices, demand for natural gas and oil, and the overall operating and economic environment. Accordingly, Comstock manages the terms of its contracts for drilling rigs and completion equipment so as to allow for maximum flexibility in responding to these changing conditions. The Company has one hydraulic fracturing fleet lease contract with a three year term. The Company's other hydraulic fracturing fleet contracts are on terms less than one year and include rights of substitution. The Company has one drilling rig contract with a three year term. The Company's other drilling rig contracts are presently either for periods of less than one year, or they are on terms that provide for cancellation with 45 days advance notice without a specified expiration date. The Company has elected not to recognize right-of-use lease assets for contracts less than one year. The costs associated with drilling and completion operations are accounted for under the successful efforts method, which generally require that these costs be capitalized as part of our proved natural gas and oil properties on our balance sheet unless they are incurred on exploration wells that are unsuccessful, in which case they are charged to exploration expense.

Lease costs recognized during the three months and nine months ended September 30, 2023 and 2022 were as follows:

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
	(In thousands)
Operating lease cost included in general and administrative expense	$	445	$	436	$	1,334	$	1,307
Operating lease cost included in lease operating expense		523		370		1,533		970
Operating lease cost included in natural gas and oil properties		18,659		9,450		41,339		15,750
Variable lease cost (completion costs included in natural gas and oil properties)		25,970		11,730		31,032		22,857
Short-term lease cost (drilling rig costs included in natural gas and oil properties)		20,098		16,102		73,986		44,242
	$	65,695	$	38,088	$	149,224	$	85,126

Cash payments for operating leases associated with right-of-use assets included in cash provided by operating activities were $1.0 million and $0.8 million for the three months ended September 30, 2023 and 2022, respectively, and $2.9 million and $2.3 million for the nine months ended September 30, 2023 and 2022, respectively. Cash payments for operating leases associated with right-of-use assets included in cash used for investing activities were $64.7 million and $37.3 million for the three months ended September 30, 2023 and 2022, respectively and $146.4 million and $82.8 million for the nine months ended September 30, 2023 and 2022, respectively.

As of September 30, 2023 and December 31, 2022, the operating leases had a weighted-average term of 2.6 years and 2.2 years, respectively, and the weighted-average discount rate used to determine the present value of future operating lease payments was 6.9% and 3.5%, respectively. As of September 30, 2023, the Company also had expected future payments for short term leased drilling services of $7.0 million.

As of September 30, 2023, expected future payments related to contracts that contain operating leases were as follows:

	(In thousands)
October 1 to December 31, 2023	$	15,291
2024		61,302
2025		58,919
2026		27,374
2027		17
Total lease payments		162,903
Imputed interest		(14,775	)
Total lease liability	$	148,128

10

COMSTOCK RESOURCES, INC.

Accrued Costs

Accrued costs at September 30, 2023 and December 31, 2022 consisted of the following:

	As of
	September 30, 2023		December 31, 2022
	(In thousands)
Accrued transportation costs	$	32,731	$	28,357
Accrued drilling costs		21,997		54,438
Accrued interest payable		19,730		54,867
Accrued income and other taxes		18,212		31,256
Accrued employee compensation		7,350		11,308
Accrued lease operating expenses		2,949		2,412
Other		697		473
	$	103,666	$	183,111

Reserve for Future Abandonment Costs

Comstock's asset retirement obligations relate to future plugging and abandonment expenses on its natural gas and oil properties and disposal of other facilities. The following table summarizes the changes in Comstock's total estimated liability for such obligations during the periods presented:

	Nine Months Ended September 30,
	2023			2022
	(In thousands)
Reserve for future abandonment costs at beginning of period	$	29,114		$	25,673
New wells placed on production		114			1,251
Acquisitions		—			1,211
Liabilities settled and assets disposed of		(42	)		(29	)
Accretion expense		1,248			1,129
Reserve for future abandonment costs at end of period	$	30,434		$	29,235

Derivative Financial Instruments and Hedging Activities

All of the Company's derivative financial instruments are used for risk management purposes and, by policy, none are held for trading or speculative purposes. Comstock minimizes credit risk to counterparties of its derivative financial instruments through formal credit policies, monitoring procedures, and diversification. The Company is not required to provide any credit support to its counterparties other than cross collateralization with the assets securing its bank credit facility. None of the Company's derivative financial instruments involve payment or receipt of premiums. The Company classifies the fair value amounts of derivative financial instruments as net current or noncurrent assets or liabilities, whichever the case may be, by commodity contract. None of the Company's derivative contracts were designated as cash flow hedges. All of Comstock's natural gas derivative financial instruments are tied to the Henry Hub-NYMEX price index.

11

COMSTOCK RESOURCES, INC.

The Company had the following natural gas price derivative financial instruments at September 30, 2023:

	Future Production Period
	Three Months Ending December 31, 2023		Year Ending December 31, 2024		Total
Natural Gas Price Swap Contracts:
Volume (MMBtu)		—		91,500,000		91,500,000
Average Price per MMBtu			$	3.55	$	3.55
Natural Gas Price Collar Contracts:
Volume (MMBtu)		23,000,000				23,000,000
Average Price per MMBtu:
Average Ceiling	$	10.28			$	10.28
Average Floor	$	3.00			$	3.00

Subsequent to September 30, 2023, the Company entered into natural gas swap contracts to hedge an additional 47,580,000 MMBtu of natural gas production from January 2024 to December 2024 at an average price of $3.56 per MMBtu.

The classification of derivative financial instruments of assets or liabilities, consists of the following:

		As of
Type	Consolidated Balance Sheet Location	September 30, 2023		December 31, 2022
		(In thousands)
Asset Derivative Financial Instruments:
Natural gas price derivatives	Derivative Financial Instruments – current	$	23,973	$	23,884
		$	23,973	$	23,884
Liability Derivative Financial Instruments:
Natural gas price derivatives	Derivative Financial Instruments – current	$	—	$	4,420
		$	—	$	4,420
Natural gas price derivatives	Derivative Financial Instruments – long-term	$	4,540	$	—
		$	4,540	$	—

The Company recognized cash settlements and changes in the fair value of its derivative financial instruments as a single component of other income (expenses). Gains and losses related to cash settlements and changes in the fair value recognized on the Company's derivative contracts recognized in the consolidated statement of operations were as follows:

	Three Months Ended September 30,					Nine Months Ended September 30,
Gain (Loss) on Derivatives Recognized in Earnings	2023		2022			2023		2022
	(In thousands)
Natural gas price derivatives	$	14,276	$	(271,335	)	$	76,190	$	(781,654	)
	$	14,276	$	(271,335	)	$	76,190	$	(781,654	)

Stock-Based Compensation

Comstock accounts for employee stock-based compensation under the fair value method. Compensation cost is measured at the grant date based on the fair value of the award and is recognized over the award vesting period and included in general and administrative expenses for awards of restricted stock and performance stock units ("PSUs") to the Company's employees and directors. The Company recognized $2.7 million and $1.8 million of stock-based compensation expense within general and administrative expenses related to awards of restricted stock and PSUs to its employees and directors during the three months ended September 30, 2023 and 2022, respectively, and $7.0 million and $4.9 million for the nine months ended September 30, 2023 and 2022, respectively.

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COMSTOCK RESOURCES, INC.

In June 2023, the Company granted an aggregate of 954,031 shares of restricted stock to its directors and employees. The grants were valued at $9.80 per share. As of September 30, 2023, Comstock had 1,430,949 shares of unvested restricted stock outstanding at a weighted average grant date fair value of $11.62 per share. Total unrecognized compensation cost related to unvested restricted stock grants of $14.3 million as of September 30, 2023 is expected to be recognized over a period of 2.2 years.

In June 2023, the Company granted an aggregate of 359,689 PSUs to its executive officers at a value of $13.64 per unit. As of September 30, 2023, Comstock had 750,399 PSUs outstanding with a weighted average grant date fair value of $15.92 per unit. The number of shares of common stock to be issued related to the PSUs is based on the Company's stock price performance as compared to its peers which could result in the issuance of anywhere from zero to 1,500,798 shares of common stock. Total unrecognized compensation cost related to these grants of $7.9 million as of September 30, 2023 is expected to be recognized over a period of 2.3 years.

Revenue Recognition

Comstock produces natural gas and oil and reports revenues separately for each of these two primary products in its statements of operations. Revenues are recognized upon the transfer of produced volumes to the Company's customers, who take control of the volumes and receive all the benefits of ownership upon delivery at designated sales points.

Gas services revenues represent sales of natural gas purchased for resale from unaffiliated third parties and fees received for gathering and treating services for certain natural gas wells operated by the Company. Revenues are recognized upon completion of the gathering and treating of contracted natural gas volumes and delivery of purchased natural gas volumes to the Company's customers. Profits and losses earned in the gathering and treating of natural gas produced by the Company's natural gas wells are eliminated in consolidation. Revenues and expenses associated with natural gas purchased for resale are presented on a gross basis in the Company's consolidated statements of operations as the Company acts as the principal in the transaction by assuming the risks and rewards from ownership of the natural gas volumes purchased and the responsibility to deliver the natural gas volumes to their sales point.

All natural gas and oil and gas services revenues are subject to contracts that have commercial substance, contain specific pricing terms, and define the enforceable rights and obligations of both parties. These contracts typically provide for cash settlement within 25 days following each production month and are cancellable upon 30 days' notice by either party for oil and vary for natural gas based upon the terms set out in the confirmations between both parties. Prices for sales of natural gas and oil are generally based upon terms that are common in the oil and gas industry, including index or spot prices, location and quality differentials, as well as market supply and demand conditions. As a result, prices for natural gas and oil routinely fluctuate based on changes in these factors. Prices for gathering and treating services are generally fixed in nature but can vary due to the quality of the gas being treated. Each unit of production (barrel of crude oil and thousand cubic feet of natural gas) represents a separate performance obligation under the Company's contracts since each unit has economic benefit on its own and each is priced separately according to the terms of the contracts.

Comstock has elected to exclude all taxes from the measurement of transaction prices, and its revenues are reported net of royalties and exclude revenue interests owned by others because the Company acts as an agent when selling natural gas and oil, on behalf of royalty owners and working interest owners. Revenue is recorded in the month of production based on an estimate of the Company's share of volumes produced and prices realized. Gas services revenue is recorded in the month the services are performed and purchased gas is sold based on an estimate of natural gas volumes and contract prices. The Company recognizes any differences between estimates and actual amounts received in the month when payment is received. Historically, differences between estimated revenues and actual revenue received have not been significant. The amount of natural gas or oil sold may differ from the amount to which the Company is entitled based on its revenue interests in the properties. The Company did not have any significant imbalance positions at September 30, 2023 or December 31, 2022.

The Company recognized accounts receivable of $157.1 million and $415.1 million as of September 30, 2023 and December 31, 2022, respectively, from purchasers for contracts where performance obligations have been satisfied and an unconditional right to consideration exists.

Credit Losses

Substantially all of the Company's accounts receivable are due from either purchasers of natural gas and oil or participants in natural gas and oil wells for which the Company serves as the operator. Generally, operators of natural gas and oil wells have the right to offset future revenues against unpaid charges related to operated wells. Natural gas and oil sales are generally unsecured. Comstock assesses the collectability of its receivables based upon their age, the credit quality of the purchaser or participant and the potential for revenue offset. The Company has not had any significant credit losses in the past and believes its accounts receivable are fully collectible. Accordingly, no allowance for doubtful accounts has been recorded for the nine months ended September 30, 2023 and 2022.

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COMSTOCK RESOURCES, INC.

Income Taxes

Deferred income taxes are provided to reflect the future tax consequences or benefits of differences between the tax basis of assets and liabilities and their reported amounts in the financial statements using enacted tax rates.

In recording deferred income tax assets, the Company considers whether it is more likely than not that its deferred income tax assets will be realized in the future. The ultimate realization of deferred income tax assets is dependent upon the generation of future taxable income during the periods in which those deferred income tax assets would be deductible. The Company believes that after considering all the available objective evidence, historical and prospective, with greater weight given to historical evidence, management is not able to determine that it is more likely than not that all of its deferred tax assets will be realized. As a result, the Company established valuation allowances for its deferred tax assets and U.S. federal and state net operating loss carryforwards that are not expected to be utilized due to the uncertainty of generating taxable income prior to the expiration of the carryforward periods. The Company will continue to assess the valuation allowances against deferred tax assets considering all available information obtained in future periods.

The following is an analysis of the consolidated income tax provision (benefit):

	Three Months Ended September 30,					Nine Months Ended September 30,
	2023			2022		2023		2022
	(In thousands)
Current - Federal	$	—		$	10,001	$	—	$	11,400
Current - State		—			14,749		—		19,821
Deferred - Federal		3,999			66,732		28,350		124,600
Deferred - State		(391	)		11,328		528		23,789
	$	3,608		$	102,810	$	28,878	$	179,610

The difference between the federal statutory rate of 21% and the effective tax rate is due to the following:

	Three Months Ended September 30,						Nine Months Ended September 30,
	2023			2022			2023			2022
Tax at statutory rate		21.0	%		21.0	%		21.0	%		21.0	%
Tax effect of:
Valuation allowance on deferred tax assets		5.5			(4.1	)		1.7			(4.0	)
State income taxes, net of federal benefit		(8.2	)		5.8			(1.6	)		5.6
Nondeductible stock-based compensation		1.7			(0.2	)		0.8			(0.1	)
Other		(0.3	)		(0.1	)		(0.1	)		—
Effective tax rate		19.7	%		22.4	%		21.8	%		22.5	%

The Company's federal income tax returns for the years subsequent to December 31, 2018 remain subject to examination. The Company's income tax returns in major state income tax jurisdictions remain subject to examination for various periods subsequent to December 31, 2019. The Company is currently under examination with the state of Louisiana and believes that its significant filing positions are highly certain and that all of its other significant income tax filing positions and deductions would be sustained under audit or the final resolution would not have a material effect on the consolidated financial statements. Therefore, the Company has not established any significant reserves for uncertain tax positions.

Fair Value Measurements

The Company holds or has held certain financial assets and liabilities that are required to be measured at fair value. These include cash and cash equivalents held in bank accounts and derivative financial instruments. Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants on the measurement date. A three-level hierarchy is followed for disclosure to show the extent and level of judgment used to estimate fair value measurements:

Level 1 — Inputs used to measure fair value are unadjusted quoted prices that are available in active markets for the identical assets or liabilities as of the reporting date.

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COMSTOCK RESOURCES, INC.

Level 2 — Inputs used to measure fair value, other than quoted prices included in Level 1, are either directly or indirectly observable as of the reporting date through correlation with market data, including quoted prices for similar assets and liabilities in active markets and quoted prices in markets that are not active. Level 2 also includes assets and liabilities that are valued using models or other pricing methodologies that do not require significant judgment since the input assumptions used in the models, such as interest rates and volatility factors, are corroborated by readily observable data from actively quoted markets for substantially the full term of the financial instrument.

Level 3 — Inputs used to measure fair value are unobservable inputs that are supported by little or no market activity and reflect the use of significant management judgment. These values are generally determined using pricing models for which the assumptions utilize management's estimates of market participant assumptions.

Fair Values – Reported

The following presents the carrying amounts and the fair values of the Company's financial instruments as of September 30, 2023 and December 31, 2022:

	As of
	September 30, 2023				December 31, 2022
	Carrying Value		Fair Value		Carrying Value		Fair Value
	(In thousands)
Assets:
Commodity-based derivatives (1)	$	23,973	$	23,973	$	23,884	$	23,884
Liabilities:
Commodity-based derivatives (1)	$	4,540	$	4,540	$	4,420	$	4,420
Bank credit facility (2)	$	345,000	$	345,000	$	—	$	—
6.75% senior notes due 2029 (3)	$	1,229,230	$	1,116,791	$	1,229,836	$	1,129,029
5.875% senior notes due 2030 (3)	$	965,000	$	829,900	$	965,000	$	846,788

(1)The Company's commodity-based derivatives are classified as Level 2 and measured at fair value using third party pricing services and other active markets or broker quotes that are readily available in the public markets.

(2)The carrying value of our floating rate debt outstanding approximates fair value.

(3)The fair value of the Company's fixed rate debt was based on quoted prices as of September 30, 2023 and December 31, 2022, respectively, a Level 1 measurement.

Earnings Per Share

Unvested restricted stock containing non-forfeitable rights to dividends are included in common stock outstanding and are considered to be participating securities and included in the computation of basic and diluted earnings per share pursuant to the two-class method. At September 30, 2023 and December 31, 2022, 1,430,949 and 966,058 shares of restricted stock, respectively, are included in common stock outstanding as such shares have a non-forfeitable right to participate in any dividends that might be declared and have the right to vote on matters submitted to the Company's stockholders.

Weighted average shares of unvested restricted stock outstanding were as follows:

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
	(In thousands)
Unvested restricted stock		1,469		890		1,186		914

PSUs represent the right to receive a number of shares of the Company's common stock that may range from zero to up to two times the number of PSUs granted on the award date based on the achievement of certain performance measures during a performance period. The number of potentially dilutive shares related to PSUs is based on the number of shares, if any, which would be issuable at the end of the respective period, assuming that date was the end of the performance period. The treasury stock method is used to measure the dilutive effect of PSUs.

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COMSTOCK RESOURCES, INC.

Weighted average unearned PSUs outstanding were as follows:

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
	(In thousands, except per unit amounts)
Weighted average PSUs		744		942		631		1,024
Weighted average grant date fair value per unit	$	15.92	$	14.52	$	15.92	$	14.52

Basic and diluted income (loss) per share for the three months and nine months ended September 30, 2023 and 2022 were determined as follows:

	Three Months Ended September 30,
	2023						2022
	Income		Shares		Per Share		Loss			Shares		Per Share
	(In thousands, except per share amounts)
Net income attributable to common stock	$	14,720					$	351,185
Income allocable to unvested restricted shares		—						(1,339	)
Basic income attributable to common stock		14,720		276,999	$	0.05		349,846			232,482	$	1.50
Effect of Dilutive Securities:
Restricted stock		—		—				1,339			392
Performance stock units		—		—				—			1,091
Convertible preferred stock		—		—				4,411			43,750
Diluted income attributable to common stock	$	14,720		276,999	$	0.05	$	355,596			277,715	$	1.28

	Nine Months Ended September 30,
	2023						2022
	Income		Shares		Per Share		Loss			Shares		Per Share
	(In thousands, except per share amounts)
Net income attributable to common stock	$	103,517					$	607,974
Income allocable to unvested restricted shares		—						(2,384	)
Basic income attributable to common stock		103,517		276,741	$	0.37		605,590			232,170	$	2.61
Effect of Dilutive Securities:
Restricted stock		—		—				2,384			541
Performance stock units		—		—				—			1,144
Convertible preferred stock		—		—				13,089			43,750
Diluted income attributable to common stock	$	103,517		276,741	$	0.37	$	621,063			277,605	$	2.24

None of the Company's participating securities participate in losses and as such are excluded from the computation of basic earnings per share during periods of net losses.

Supplementary Information with Respect to the Consolidated Statements of Cash Flows

Cash payments made for interest and income taxes and other non-cash investing activities for the nine months ended September 30, 2023 and 2022, respectively, were as follows:

	Nine Months Ended September 30,
	2023			2022
	(In thousands)
Cash payments for:
Interest payments	$	150,239		$	164,106
Income tax payments	$	29,796		$	719
Non-cash investing activities include:
Increase (decrease) in accrued capital expenditures	$	(32,441	)	$	16,202
Liabilities assumed in exchange for right-of-use lease assets	$	157,789		$	109,546

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COMSTOCK RESOURCES, INC.

(2) LONG-TERM DEBT

At September 30, 2023, long-term debt was comprised of the following:

	(In thousands)
6.75% Senior Notes due 2029:
Principal	$	1,223,880
Premium, net of amortization		5,350
5.875% Senior Notes due 2030:
Principal		965,000
Bank Credit Facility:
Principal		345,000
Debt issuance costs, net of amortization		(35,823	)
	$	2,503,407

As of September 30, 2023, the Company had $345.0 million outstanding under a bank credit facility. Aggregate commitments under the bank credit facility are $1.5 billion, which matures on November 15, 2027. Borrowings under the bank credit facility are subject to a borrowing base, which is currently set at $2.0 billion. The borrowing base is re-determined on a semi-annual basis and upon the occurrence of certain other events. Borrowings under the bank credit facility are secured by substantially all of the assets of the Company and its subsidiaries and bear interest at the Company's option, at either SOFR plus 1.75% to 2.75% or an alternate base rate plus 0.75% to 1.75%, in each case depending on the utilization of the borrowing base. The Company also pays a commitment fee of 0.375% to 0.5% on the unused portion of the borrowing base. The bank credit facility places certain restrictions upon the Company's and its subsidiaries' ability to, among other things, incur additional indebtedness, pay cash dividends, repurchase common stock, make certain loans, investments and divestitures and redeem the senior notes. The only financial covenants are the maintenance of a leverage ratio of less than 3.5 to 1.0 and an adjusted current ratio of at least 1.0 to 1.0. The Company was in compliance with the covenants as of September 30, 2023.

During the nine months ended September 30, 2022, the Company completed the early redemption of all of its outstanding 7.5% senior notes due in 2025 for an aggregate amount of $258.1 million and repurchased $26.1 million principal amount of its 6.75% senior notes due in 2029 for $24.9 million. As a result of the redemption and repurchase, the Company recognized a loss of $46.8 million on early retirement of debt.

(3) COMMITMENTS AND CONTINGENCIES

In December 2022, the Company entered into agreements for three new drilling rigs with a three year term and a minimum annual commitment of $12.2 million per drilling rig. Comstock took delivery of one of the rigs during August 2023 and expects to take delivery of the second rig in the fourth quarter of 2023 and the third rig in early 2024.

From time to time, the Company is involved in certain litigation that arises in the normal course of its operations. The Company records a loss contingency for these matters when it is probable that a liability has been incurred and the amount of the loss can be reasonably estimated. The Company does not believe the resolution of these matters will have a material effect on the Company's financial position, results of operations or cash flows and no material amounts are accrued relative to these matters at September 30, 2023 or 2022.

(4) RELATED PARTY TRANSACTIONS

Comstock operates natural gas and oil properties held by partnerships owned by its majority stockholder. The Company charges the partnerships for the costs incurred to drill, complete and produce wells, as well as drilling and operating overhead fees. Comstock also provides natural gas marketing services to the partnerships, including evaluating potential markets and providing hedging services, in return for a fee equal to $0.02 per Mcf for natural gas marketed. The Company received $327 thousand and $152 thousand for the three months ended September 30, 2023 and 2022, respectively, and $1.0 million and $735 thousand for the nine months ended September 30, 2023 and 2022, respectively, for drilling, operating and marketing services provided to the partnerships. The fees received for the services are reflected as a reduction of general and administrative expenses in the accompanying consolidated statements of operations.

In connection with the operation of the wells, the Company had a $21.2 million and $18.5 million receivable from the partnerships at September 30, 2023 and December 31, 2022, respectively.

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COMSTOCK RESOURCES, INC.

(5) SUBSEQUENT EVENT

On October 30, 2023, the board of directors of the Company authorized a dividend of $0.125 per share to be paid on December 15, 2023 to common stockholders of record on December 1, 2023.

On October 30, 2023, Comstock entered into a midstream partnership for the Company's Western Haynesville acreage with Quantum Capital Solutions ("QCS"), an affiliate of Quantum Capital Group. In connection with this transaction, Comstock contributed its Pinnacle gathering and treating system, which is comprised of a 145-mile high pressure pipeline and the Bethel natural gas processing plant to the partnership in exchange for a total capital commitment by QCS of $300 million to fund the future build-out of the Western Haynesville midstream system. Comstock will control and operate the midstream system.

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COMSTOCK RESOURCES, INC.

ITEM 2: MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

This report contains forward-looking statements that involve risks, uncertainties and assumptions that are made pursuant to the safe harbor provisions of the Private Securities Litigation Reform Act of 1995 including those described under the heading "Risk Factors" in our Annual Report on Form 10-K for the year ended December 31, 2022 (the "Annual Report"). Actual results may differ materially from those anticipated in our forward-looking statements due to many factors. The following discussion should be read in conjunction with the consolidated financial statements and notes thereto included in this report and in our Annual Report.

Results of Operations

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
	(In thousands except per unit amounts)
Net Production Data:
Natural gas (MMcf)		130,528		128,902		383,902		367,758
Oil (MBbls)		17		21		57		66
Natural gas equivalent (MMcfe)		130,629		129,025		384,241		368,152
Revenues:
Natural gas sales	$	304,141	$	994,979	$	911,065	$	2,376,774
Oil sales		1,309		1,936		4,111		6,324
Total natural gas and oil sales	$	305,450	$	996,915	$	915,176	$	2,383,098
Expenses:
Production and ad valorem taxes	$	25,386	$	24,531	$	59,891	$	60,080
Gathering and transportation	$	47,012	$	44,740	$	137,981	$	113,797
Lease operating	$	31,664	$	28,608	$	100,525	$	79,873
Exploration	$	—	$	—	$	1,775	$	3,363
Average Sales Price:
Natural gas (per Mcf)	$	2.33	$	7.72	$	2.37	$	6.46
Oil (per Bbl)	$	77.00	$	92.19	$	72.12	$	95.82
Average equivalent (Mcfe)	$	2.34	$	7.73	$	2.38	$	6.47
Expenses ($ per Mcfe):
Production and ad valorem taxes	$	0.20	$	0.19	$	0.16	$	0.16
Gathering and transportation	$	0.36	$	0.35	$	0.36	$	0.31
Lease operating	$	0.24	$	0.22	$	0.26	$	0.22
Gas Services:
Gas services revenue	$	71,287	$	193,090	$	239,350	$	322,575
Gas services expense	$	67,632	$	181,818	$	224,317	$	305,271

Revenues –

Natural gas and oil sales of $305.5 million for the third quarter of 2023 decreased by $691.5 million (69%) as compared to $996.9 million for the third quarter of 2022. The decrease was primarily due to lower natural gas prices in the third quarter of 2023 as compared with 2022 prices. Our natural gas production for the third quarter of 2023 increased 1% to 130.5 billion cubic feet ("Bcf") (1.4 Bcf per day), and was sold at an average price of $2.33 per thousand cubic feet ("Mcf"). Our natural gas production for the third quarter of 2022 was 128.9 Bcf (1.4 Bcf per day) and was sold at an average price of $7.72 per Mcf.

Natural gas and oil sales of $915.2 million for the nine months ended September 30, 2023 decreased by $1.5 billion (62%) as compared to $2.4 billion for the nine months ended September 30, 2022, which was also primarily due to lower natural gas prices during the first nine months of 2023 as compared with 2022 prices. Our natural gas production for the first nine months of 2023 increased 4% to 383.9 Bcf (1.4 Bcf per day), and was sold at an average price of $2.37 per Mcf as compared to 367.8 Bcf (1.3 Bcf per day) sold at an average price of $6.46 in the first nine months of 2022.

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COMSTOCK RESOURCES, INC.

We utilize natural gas price derivative financial instruments to manage our exposure to changes in prices of natural gas and to protect returns on investment from our drilling activities. The following table presents our natural gas prices before and after the effect of cash settlements of our derivative financial instruments:

	Three Months Ended September 30,					Nine Months Ended September 30,
	2023		2022			2023		2022
Average Realized Natural Gas Price:
Natural gas, per Mcf	$	2.33	$	7.72		$	2.37	$	6.46
Cash settlements on derivative financial instruments, per Mcf		0.08		(2.36	)		0.20		(1.84	)
Price per Mcf, including cash settlements on derivative financial instruments	$	2.41	$	5.36		$	2.57	$	4.62

Gas service revenues of $71.3 million decreased $121.8 million (63%) for the third quarter of 2023 from $193.1 million in the third quarter of 2022. Gas service revenues of $239.4 million decreased $83.2 million (26%) for the first nine months of 2023 from $322.6 million for the first nine months of 2022. Gas service activities commenced in April 2022 with the acquisition of a pipeline and gas treating plant and the opportunity to utilize our excess transport capacity in North Louisiana. Gas services revenues decreased for the three and nine months ended September 30, 2023 as compared to 2022 due to lower natural gas prices on sales of natural gas purchased to utilize our excess transport capacity.

Costs and Expenses –

Our production and ad valorem taxes increased $0.9 million (3%) to $25.4 million for the third quarter of 2023 from $24.5 million in the third quarter of 2022. The increase was primarily related to increases in Louisiana production tax and ad valorem tax rates, partially offset by lower natural gas and oil sales during 2023. Production and ad valorem taxes decreased $0.2 million to $59.9 million for the first nine months of 2023 from $60.1 million in the first nine months of 2022. The decrease was primarily related to lower natural gas and oil sales during 2023.

Gathering and transportation costs for the third quarter of 2023 increased $2.3 million (5%) to $47.0 million as compared to $44.7 million in the third quarter of 2022. Gathering and transportation costs for the first nine months of 2023 increased $24.2 million (21%) to $138.0 million as compared to $113.8 million for the first nine months of 2022. The increase is due to production growth in areas with higher average gathering and transportation rates.

Our lease operating expense of $31.7 million ($0.24 per Mcfe) for the third quarter of 2023 increased $3.1 million (11%) from lease operating expense of $28.6 million ($0.22 per Mcfe) for the third quarter of 2022. Lease operating expense of $100.5 million ($0.26 per Mcfe) for the first nine months of 2023 increased $20.7 million (26%) from lease operating expense of $79.9 million ($0.22 per Mcfe) for the first nine months of 2022. The increase was due primarily to increased water disposal and other production costs.

Gas service expenses of $67.6 million decreased $114.2 million (63%) for the third quarter of 2023 from $181.8 million in the third quarter of 2022. Gas service expenses of $224.3 million decreased $81.0 million (27%) for the first nine months of 2023 from $305.3 million for the first nine months of 2022. The decrease is due primarily to lower natural gas prices realized on purchases of third party natural gas for resale.

Depreciation, depletion and amortization ("DD&A") increased $19.1 million to $148.2 million in the third quarter of 2023 from $129.1 million in the third quarter of 2022. Our DD&A per equivalent Mcf produced was $1.13 per Mcfe for the quarter ended September 30, 2023 as compared to $1.00 for the quarter ended September 30, 2022. DD&A increased $67.4 million to $422.4 million for the first nine months of 2023 from $355.0 million during the first nine months of 2022. Our DD&A per equivalent Mcf produced was $1.10 per Mcfe for the nine months ended September 30, 2023 as compared to $0.96 for the nine months ended September 30, 2022. The increase in the DD&A rate was primarily due to higher drilling and completion costs incurred for wells turned to sales in the three months and nine months ended September 30, 2023.

General and administrative expenses, which are reported net of overhead reimbursements, decreased to $9.6 million for the third quarter of 2023 as compared to $10.2 million in the third quarter of 2022. The decrease was primarily related to lower personnel costs. General and administrative expenses increased to $32.0 million for the first nine months of 2023 as compared to $27.5 million during the first nine months of 2022. The increase was primarily related to higher personnel costs.

We use derivative financial instruments as part of our price risk management program to protect our capital investments. During the quarter ended September 30, 2023, we had net gains related to our derivative financial instruments of $14.3 million, as compared to net losses on derivative financial instruments of $271.3 million during the quarter ended September 30, 2022. Realized net gains from our price risk management program were $10.3 million for the quarter ended September 30, 2023 as compared to realized net losses of

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COMSTOCK RESOURCES, INC.

$304.5 million for the quarter ended September 30, 2022. Net gains on derivative financial instruments were $76.2 million for the first nine months of 2023 as compared to net losses of $781.7 million for the first nine months of 2022. Realized net gains from our price risk management program were $76.2 million for the first nine months of 2023 as compared to realized net losses of $679.0 million for the first nine months of 2022.

Interest expense was $43.6 million and $41.4 million for the quarters ended September 30, 2023 and 2022, respectively, and $121.1 million and $132.2 million for the nine months ended September 30, 2023 and 2022, respectively. The increase in interest expense for the quarters ended September 30, 2023 and 2022 was due primarily to borrowings under the bank credit facility. The decrease in interest expense for the nine months ended September 30, 2023 and 2022 was due primarily to the early retirements of senior notes in May and June 2022 and the repayment of outstanding borrowings under the bank credit facility in 2022.

Loss on extinguishment of debt was $46.8 million for the nine months ended September 30, 2022. In May and June 2022, we retired $244.4 million and $26.1 million, respectively, principal amount of our 7.5% senior notes due in 2025 and 6.75% senior notes due in 2029.

Income taxes for the quarter ended September 30, 2023 and 2022 were a provision of $3.6 million and $102.8 million, respectively. Income taxes for the nine months ended September 30, 2023 and 2022 were a provision of $28.9 million and $179.6 million, respectively. Income tax expense for the quarters ended September 30, 2023 and 2022 reflect an effective tax rate of 19.7% and 22.4%, respectively. Income tax expense for the nine months ended September 30, 2023 and 2022 reflect an effective tax rate of 21.8% and 22.5%, respectively. The difference between the federal statutory tax rate of 21% and our effective rate is primarily attributable to the impact of state income taxes and revisions to the estimated future utilization of federal and state net operating loss carryforwards.

We reported net income available to common stockholders of $14.7 million or $0.05 per share, for the quarter ended September 30, 2023. Income from operations for the third quarter of 2023 was $47.3 million. We reported net income available to common stockholders of $351.2 million or $1.28 per diluted share for the quarter ended September 30, 2022. In the first nine months of 2023, we reported net income available to common stockholders of $103.5 million or $0.37 per diluted share. Income from operations for the first nine months of 2023 was $175.8 million. We reported net income available to common stockholders of $608.0 million or $2.24 per diluted share for the nine months ended September 30, 2022.

Cash Flows, Liquidity and Capital Resources

Cash Flows

The following table summarizes sources and uses of cash and cash equivalents:

	Nine Months Ended September 30,
	2023		2022
	(In thousands)
Sources of cash and cash equivalents:
Operating activities	$	788,639	$	1,230,056
Borrowings on bank credit facility, net of repayments		345,000		(135,000	)
Proceeds from asset sales		41,295		93
Total	$	1,174,934	$	1,095,149
Uses of cash and cash equivalents:
Capital expenditures	$	1,103,527	$	793,900
Retirement of senior notes		—		273,920
Common stock dividends		104,181		—
Preferred stock dividends		—		13,089
Other		2,043		6,255
Total	$	1,209,751	$	1,087,164

Cash flows from operating activities. Net cash provided by our operating activities decreased $441.4 million (36%) to $788.6 million in the first nine months of 2023 from $1,230.1 million in the same period in 2022. The decrease was due primarily to lower natural gas and oil sales.

Proceeds from asset sales. In the second quarter of 2023, we sold our interest in certain non-operated properties for net proceeds of $41.3 million.

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COMSTOCK RESOURCES, INC.

Retirement of senior notes. In May 2022, we retired all of our outstanding 7.5% senior notes due in 2025 for $248.9 million, which included premiums paid over face value of $4.5 million. During June 2022, we retired $26.1 million principal amount of our 6.75% senior notes for $24.9 million.

Common stock dividends. During the first nine months of 2023, we paid quarterly cash dividends of $0.125 per common share to stockholders of record as of March 1, 2023, June 1, 2023 and September 1, 2023, respectively.

Capital expenditures. The increase in capital expenditures of $309.6 million is primarily due to our higher drilling and completion activity in the first nine months of 2023 and $76.6 million of unproved property acquisitions.

Our capital expenditures are summarized in the following table:

	Nine Months Ended September 30,
	2023			2022
	(In thousands)
Acquisitions:
Proved property	$	—		$	205
Unproved property		76,646			37,396
Exploration and development:
Development leasehold costs		19,087			8,298
Exploratory drilling and completion costs		179,049			49,003
Development drilling and completion costs		740,808			619,373
Other development costs		18,868			52,500
Asset retirement obligations		71			1,223
Total exploration and development		1,034,529			767,998
Other property and equipment		22,076			18,815
Total capital expenditures	$	1,056,605		$	786,813
Change in accrued capital expenditures and other		32,441			(16,231	)
Prepaid drilling costs		14,594			25,752
Change in asset retirement obligations		(113	)		(2,434	)
Total cash capital expenditures	$	1,103,527		$	793,900

We drilled 52 (41.3 net) wells and completed 57 (43 net) Haynesville and Bossier shale operated wells during the first nine months of 2023. We currently expect to spend an additional $300 million to $400 million in the remaining three months of 2023 on drilling, completion, infrastructure and other activity.

Liquidity and Capital Resources

As of September 30, 2023, we had $1.2 billion of liquidity, comprised of unused borrowing capacity under our bank credit facility and $19.8 million of cash and cash equivalents on hand. Our short and long-term capital requirements consist primarily of funding our development and exploration activities, acquisitions, payments of contractual obligations and debt service.

We expect to fund our future development and exploration activities with future operating cash flow and borrowings under our bank credit facility. The timing of most of our future capital expenditures is discretionary because of the limited number of material long-term capital expenditure commitments. Consequently, we have a significant degree of flexibility to adjust the level of our capital expenditures as circumstances warrant. We believe that our cash provided by operations and borrowings available under our bank credit facility will be sufficient to satisfy our foreseeable liquidity needs and capital expenditure requirements for at least the next twelve months. If our plans or assumptions change or our assumptions prove to be inaccurate, we may be required to seek additional capital, including debt or equity financing. We cannot provide any assurance that we will be able to obtain such capital, or if such capital is available, that we will be able to obtain it on acceptable terms.

We do not have a specific acquisition budget for the remainder of 2023 because the timing and size of acquisitions are unpredictable. We intend to use our cash flows from operations, borrowings under our bank credit facility, or other debt or equity financings to the extent available, to finance such acquisitions. The availability and attractiveness of these sources of financing will depend upon a number of factors, some of which will relate to our financial condition and performance and some of which will be beyond our control, such as prevailing interest rates, natural gas and oil prices and other market conditions. Lack of access to the debt or equity markets due to general economic conditions could impede our ability to complete acquisitions.

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COMSTOCK RESOURCES, INC.

At September 30, 2023, we had $345.0 million of borrowings outstanding under our bank credit facility. Aggregate commitments under our bank credit facility are $1.5 billion, which matures on November 15, 2027. Borrowings under the bank credit facility are subject to a borrowing base, which was redetermined on October 27, 2023 and currently set at $2.0 billion. The borrowing base is re-determined on a semi-annual basis and upon the occurrence of certain other events. Borrowings under the bank credit facility are secured by substantially all of our assets and those of our subsidiaries and bear interest at our option, at either adjusted SOFR plus 1.75% to 2.75% or an alternate base rate plus 0.75% to 1.75%, in each case depending on the utilization of the borrowing base. We also pay a commitment fee of 0.375% to 0.50% on the unused portion of the borrowing base. The bank credit facility places certain restrictions upon our and our subsidiaries' ability to, among other things, incur additional indebtedness, pay cash dividends, repurchase common stock, make certain loans, investments and divestitures and redeem the senior notes. The only financial covenants are the maintenance of a leverage ratio of less than 3.5 to 1.0 and an adjusted current ratio of at least 1.0 to 1.0. We were in compliance with the covenants as of September 30, 2023.

Income Taxes

At September 30, 2023, we had $767.5 million in U.S. federal net operating loss ("NOL") carryforwards and $1.5 billion in certain state NOL carryforwards. As a result of the change of control in August 2018, our ability to use NOLs to reduce taxable income is generally limited to an annual amount based on the fair market value of our stock immediately prior to the ownership change multiplied by the long-term tax-exempt interest rate. Our NOLs are estimated to be limited to $3.3 million a year as a result of this limitation. In addition to this limitation, IRC Section 382 provides that a corporation with a net unrealized built-in gain immediately before an ownership change may increase its limitation by the amount of recognized built-in gain recognized during a recognition period, which is generally the five-year period immediately following an ownership change. Based on the fair market value of our common stock immediately prior to the ownership change, we believe that we have a net unrealized built-in gain which will increase the Section 382 limitation during the five-year recognition period from 2018 to 2023 by $147.7 million.

NOLs that exceed the Section 382 limitation in any year continue to be allowed as carryforwards until they expire and can be used to offset taxable income for years within the carryover period subject to the limitation in each year. NOLs incurred prior to 2018 generally have a 20-year life until they expire. NOLs generated in 2018 and after would be carried forward indefinitely. Our use of new NOLs arising after the date of an ownership change would not be affected by the 382 limitation. If we do not generate a sufficient level of taxable income prior to the expiration of the pre-2018 NOL carryforward periods, then we will lose the ability to apply those NOLs as offsets to future taxable income. We estimate that $766.2 million of the U.S. federal NOL carryforwards and $1.3 billion of the estimated state NOL carryforwards will expire unused.

ITEM 3: QUANTITATIVE AND QUALITATIVE DISCLOSURE ABOUT MARKET RISK

Natural Gas and Oil Prices

Our financial condition, results of operations and capital resources are highly dependent upon the prevailing market prices of natural gas and oil. These commodity prices are subject to wide fluctuations and market uncertainties due to a variety of factors, some of which are beyond our control. Factors influencing natural gas and oil prices include the level of global demand for oil, the foreign supply of natural gas and oil, the effect of the war in Ukraine and the geopolitical response to Russia's invasion, the establishment of and compliance with production quotas by oil exporting countries, weather conditions that determine the demand for natural gas, the price and availability of alternative fuels and overall economic conditions. It is impossible to predict future natural gas and oil prices with any degree of certainty. Sustained weakness in natural gas and oil prices may adversely affect our financial condition and results of operations, and may also reduce the amount of natural gas and oil reserves that we can produce economically. Any reduction in our natural gas and oil reserves, including reductions due to price fluctuations, can have an adverse effect on our ability to obtain capital for our exploration and development activities. Similarly, any improvements in natural gas and oil prices can have a favorable impact on our financial condition, results of operations and capital resources.

As of September 30, 2023, we had natural gas price collars to hedge approximately 23.0 Bcf of our 2023 natural gas production with an average floor price of $3.00 per MMBtu and an average ceiling price of $10.28 per MMBtu and we had natural gas price swaps to hedge approximately 91.5 Bcf of our 2024 natural gas production at an average price of $3.55 per MMBtu. None of our derivative contracts have margin requirements or collateral provisions that could require funding prior to the scheduled cash settlement date.

An increase of 10% in the market price of natural gas on September 30, 2023 would decrease the fair value of our natural gas price swaps and collars by approximately $2.6 million. A decrease of 10% in the market price of natural gas on September 30, 2023 would increase the fair value of our natural gas price swaps and collars by approximately $3.5 million. The impact of hypothetical changes in market prices of natural gas on our natural gas derivative financial instruments discussed above does not include the offsetting impact that the same hypothetical changes in market prices of natural gas may have on our physical sales of natural gas. Since our outstanding natural gas derivative financial instruments hedge only a portion of our forecasted physical gas production, a positive or negative impact to the fair value of our natural gas derivative financial instruments would be partially offset by our physical sales of natural gas.

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COMSTOCK RESOURCES, INC.

Interest Rates

At September 30, 2023, we had approximately $2.5 billion principal amount of long-term debt outstanding. $965.0 million of our long-term debt bear interest at a fixed rate of 5.875% and $1.22 billion of our long-term debt bear interest at a fixed rate of 6.75%. As of September 30, 2023, the fair market value of the 5.875% senior notes due in 2030 and the 6.75% senior notes due in 2029 was $829.9 million and $1.1 billion, respectively, based on the market price of approximately 86% and 91%, respectively, of the face amount of such debt. At September 30, 2023, we had $345.0 million outstanding under our bank credit facility, which is subject to variable rates of interest that are tied to SOFR or the corporate base rate, at our option. Any increase in these interest rates would have an adverse impact on our results of operations and cash flow.

ITEM 4: CONTROLS AND PROCEDURES

As of September 30, 2023, we carried out an evaluation, under the supervision and with the participation of our chief executive officer and chief financial officer, of the effectiveness of the design and operation of our disclosure controls and procedures (as defined in Rule 13a-15(e) under the Securities Exchange Act of 1934). Based on this evaluation, our chief executive officer and chief financial officer concluded that our disclosure controls and procedures were effective as of September 30, 2023 to provide reasonable assurance that information required to be disclosed by us in the reports filed or submitted by us under the Securities Exchange Act of 1934 is recorded, processed, summarized and reported within the time periods specified in the SEC's rules and forms, and to provide reasonable assurance that information required to be disclosed by us is accumulated and communicated to our management, including our chief executive officer and chief financial officer, as appropriate, to allow timely decisions regarding required disclosure. There were no changes in our internal controls over financial reporting (as such term is defined in Rule 13a-15(f) under the Securities Exchange Act of 1934) that occurred during the three months ended September 30, 2023 that has materially affected, or is reasonably likely to materially affect, our internal controls over financial reporting.

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COMSTOCK RESOURCES, INC.

PART II — OTHER INFORMATION

ITEM 1A. RISK FACTORS

We are subject to various risks and uncertainties in the course of our business. For a discuss of such risks and uncertainties, please see "Item 1A. Risk Factors" in the Annual Report. There has been no material changes to the Risk Factors we have disclosed in the Annual Report.

ITEM 5: OTHER INFORMATION

During the three months ended September 30, 2023, none of our directors or officers adopted or terminated a "Rule 10b5-1 trading arrangement" or "non-Rule 10b5-1 trading arrangement," as those terms are defined in Regulation S-K, Item 408(a).

ITEM 6: EXHIBITS

Exhibit No.	Description
10.1	First Amendment to Second Amended and Restated Credit Agreement dated as of October 27, 2023 among the Company, Wells Fargo Bank National Association as Administrative Agent and the lenders party thereto from time to time.
31.1*	Section 302 Certification of the Chief Executive Officer.
31.2*	Section 302 Certification of the Chief Financial Officer.
32.1†	Certification for the Chief Executive Officer as required by Section 906 of the Sarbanes-Oxley Act of 2002.
32.2†	Certification for the Chief Financial Officer as required by Section 906 of the Sarbanes-Oxley Act of 2002.
101.INS*	Inline XBRL Instance Document
101.SCH*	Inline XBRL Schema Document
101.CAL*	Inline XBRL Calculation Linkbase Document
101.LAB*	Inline XBRL Labels Linkbase Document
101.PRE*	Inline XBRL Presentation Linkbase Document
101.DEF*	Inline XBRL Definition Linkbase Document
104*	Cover Page Interactive Data File (embedded within the Inline XBRL document)

_____________________________

* Filed herewith.

† Furnished herewith.

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COMSTOCK RESOURCES, INC.

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

	COMSTOCK RESOURCES, INC.
Date: November 2, 2023	/s/ M. JAY ALLISON
	M. Jay Allison, Chairman and Chief Executive Officer
	(Principal Executive Officer)
Date: November 2, 2023	/s/ ROLAND O. BURNS
	Roland O. Burns, President, Chief Financial Officer and Secretary
	(Principal Financial and Accounting Officer)

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EX-10.1

EXHIBIT 10.1

FIRST AMENDMENT TO SECOND AMENDED AND RESTATED CREDIT AGREEMENT

This FIRST AMENDMENT TO SECOND AMENDED AND RESTATED CREDIT AGREEMENT (this “Amendment”) dated as of October 27, 2023, is among COMSTOCK RESOURCES, INC. (the “Borrower”), the Lenders (as defined below) party hereto, and WELLS FARGO BANK, N.A., as administrative agent for the Lenders (in such capacity, together with its successors and assigns, the “Administrative Agent”).

PRELIMINARY STATEMENT

A.The Borrower, the Administrative Agent, certain banks and other financial institutions, as lenders (the “Lenders” and each a “Lender”), and certain other parties have entered into that certain Second Amended and Restated Credit Agreement dated as of November 15, 2022 (as amended, restated, supplemented or otherwise modified from time to time prior to the date hereof, the “Existing Credit Agreement”; and the Existing Credit Agreement as amended by this Amendment, the “Credit Agreement”), pursuant to which the Lenders have, subject to the terms and conditions set forth therein, made certain credit available to and on behalf of the Borrower.

B.The Borrower, the Administrative Agent and the Lenders party hereto desire to enter into this amendment to, among other things, (i) amend the Existing Credit Agreement as set forth in Section 2 hereof and (ii) evidence the reaffirmation of the Borrowing Base at $2,000,000,000 as set forth in Section 3 hereof.

NOW THEREFORE, in consideration of the foregoing and the mutual agreements set forth herein and other good and valuable consideration, the parties agree as follows:

Section 1.Definitions. Unless otherwise defined in this Amendment, each capitalized term used in this Amendment has the meaning assigned to such term in the Credit Agreement.

Section 2.Amendments to the Existing Credit Agreement.

(a)Section 1.1 of the Existing Credit Agreement is hereby amended to add in appropriate alphabetical order the following definitions which shall read in their entirety as follows:

“First Amendment” means that certain First Amendment to Second Amended and Restated Credit Agreement, dated as of the First Amendment Effective Date, among the Borrower, the Guarantors party thereto, the Administrative Agent and the Lenders party thereto.

“First Amendment Effective Date” means October 27, 2023.

“Midstream Assets” means all gathering systems and pipeline systems and all equipment, processing, separating, compressor, treatment, storage, transportation, extraction, exchange or manufacturing facilities or other similar facilities related thereto, all natural gas, all liquid product and other storage tanks,

liquid product truck loading terminals and any other assets used in connection with, and contracts, permits and other rights in respect of, in each case, the gathering, treating, transporting, handling, filtering, recycling, storing or processing of Hydrocarbons, carbon dioxide and/or water.

“PGT” means Pinnacle Gas Treating LLC, a Texas limited liability company.

“PGS” means Pinnacle Gas Services LLC, a Delaware limited liability company.

“Pinnacle Midstream Assets” means the Midstream Assets located in Robertson, Leon, Freestone, Anderson and Limestone counties in Texas and owned by PGT as of the First Amendment Effective Date. For the avoidance of doubt, “Pinnacle Midstream Assets” does not include any Oil and Gas Properties to which Proved Reserves are attributable.

“Specified PGT Contribution” means the contribution by Comstock Gas Services LLC of 100% of the Equity Interests of PGT to PGS.

(b)The definition of “Loan Documents” contained in Section 1.1 of the Existing Credit Agreement is hereby amended and restated in its entirety to read as follows:

“Loan Documents” means this Agreement, the Notes, the Fee Letter, the Letter of Credit Agreements, the Letters of Credit, the Security Instruments, the First Amendment, and any other document identified as a “Loan Document” delivered in connection with this Agreement from time to time, in each case, as the same may be amended, modified, supplemented or restated from time to time.

(c)Section 8.01(a) of the Existing Credit Agreement is hereby amended and restated in its entirety to read as follows:

(a) Annual Financial Statements. Within ninety (90) days after the end of each fiscal year of the Borrower, commencing with the fiscal year ending December 31, 2022, the audited consolidated balance sheets of the Borrower and its Consolidated Subsidiaries as at the end of such fiscal year and related statements of operations, and cash flows as of the end of and for such year, setting forth, in comparative form the figures for the previous fiscal year, by independent public accountants of recognized national standing reasonably acceptable to the Administrative Agent (without any qualification or exception which (x) is of a “going concern” or similar nature, or (y) relates to the limited scope of examination of matters relevant to such financial statement (other than in the case of clauses (x) and (y), resulting from (1) the impending maturity of the Indebtedness hereunder or (ii) any prospective breach of any financial covenant)) to the effect that such consolidated financial statements present fairly, in all material respects, the financial position and results of operations of the Borrower and its Consolidated Subsidiaries on a consolidated basis in accordance with GAAP consistently applied (except for changes in accounting principles and changes in accounting estimates

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required by GAAP and disclosed to the Administrative Agent in writing or otherwise disclosed in the footnotes to the financial statements).

(d)Section 8.01(b) of the Existing Credit Agreement is hereby amended and restated in its entirety to read as follows:

(b) Quarterly Financial Statements. Within forty five (45) days after the end of each of the first three fiscal quarters of each fiscal year of the Borrower, commencing with the fiscal quarter ending September 30, 2022, the consolidated balance sheets of the Borrower and its Consolidated Subsidiaries and related statements of operations, stockholders’ equity and cash flows, in each case, as of the end of and for such fiscal quarter and the then elapsed portion of the fiscal year, setting forth, in each case, in comparative form the figures for the corresponding period or periods of (or, in the case of the balance sheet, as of the end of) the previous fiscal year, all certified by one of its Financial Officers as presenting fairly, in all material respects, the financial position and results of operations of the Borrower and its Consolidated Subsidiaries on a consolidated basis in accordance with GAAP consistently applied (except for changes in accounting principles and changes in accounting estimates required by GAAP), subject to normal year-end adjustments and the absence of footnotes.

(e)Section 8.01(c) of the Existing Credit Agreement is hereby amended and restated in its entirety to read as follows:

(c) Certificate of Financial Officer – Compliance. Concurrently with any delivery of financial statements under Section 8.01(a) or Section 8.01(b), (i) a certificate of a Financial Officer in substantially the form of Exhibit B hereto (A) certifying as to whether a Default has occurred and, if a Default has occurred, specifying the details thereof and any action taken or proposed to be taken with respect thereto, (B) setting forth reasonably detailed calculations demonstrating compliance with Section 9.01 and (C) stating whether any change in GAAP or in the application thereof has occurred since the date of the audited financial statements referred to in Section 7.04(a) and, if any such change has occurred, specifying the effect of such change on the financial statements accompanying such certificate; provided that the Borrower shall not be required to restate or recast any financial statement unless required by GAAP and (ii) separate consolidating schedules or spreadsheets reflecting the balance sheet information, income and cash flows of the Unrestricted Subsidiaries and reconciling such information to the financial statements described above, in such form as would be presentable to the auditors of the Borrower and otherwise in form and detail reasonably satisfactory to the Administrative Agent.

(f)Section 8.01 of the Existing Credit Agreement is hereby amended by adding a new subsection (w) to read in its entirety as follows:

(w) (i) Not later than five (5) Business Days (or such later date as the Administrative Agent may agree in its sole discretion) prior to the consummation

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of the Specified PGT Contribution, substantially final drafts of (A) all organizational documents and other material agreements related to the Specified PGT Contribution and (B) all contracts and agreements to be entered into between PGT or PGS, on the one hand, and the Borrower or any of its Restricted Subsidiaries on the other hand, on or about the date the Specified PGT Contribution is consummated, (ii) not later than one (1) Business Day (or such later date as the Administrative Agent may agree in its sole discretion) after the consummation of the Specified PGT Contribution, executed copies of the agreements referred to in the foregoing clause (i) and (iii) if PGT ceases to be a Subsidiary of the Borrower on or after the First Amendment Effective Date, not later than one (1) Business Day (or such later date as the Administrative Agent may agree in its sole discretion) after PGT subsequently becomes a Subsidiary of the Borrower, written notice thereof.

(g)Section 9.05(e) of the Existing Credit Agreement is hereby amended and restated in its entirety to read as follows:

(e) (i) Dispositions constituting an Investment permitted under Section 9.06, including the Specified PGT Contribution, and (ii) Dispositions among the Borrower and the Guarantors that are Wholly Owned Subsidiaries; provided that both before and after giving effect to such Disposition, the Borrower and the Restricted Subsidiaries are in compliance with Section 8.14(c) as of the date of such Disposition without giving effect to the 30‑day grace period specified in such Section;

(h)Section 9.06 of the Existing Credit Agreement is hereby amended by (i) deleting “and” at the end of clause (k), (ii) adding “and” at the end of clause (l) and (iii) adding the following new clause (m) immediately after clause (l) to read in its entirety as follows:

(m) the Specified PGT Contribution so long as (i) at the time of, and immediately after giving pro forma effect thereto, (A) PGT owns no assets other than the Pinnacle Midstream Assets and (B) no Event of Default or Borrowing Base Deficiency would exist and (ii) if PGT would be a Subsidiary of the Borrower immediately after the consummation of the Specified PGT Contribution, concurrently with the consummation thereof, PGT has been designated as an Unrestricted Subsidiary (A) under this Agreement in accordance with Section 9.23 and (B) under the Senior Notes Documents in accordance with the terms thereof;

(i)The proviso at the end of Section 9.06 of the Existing Credit Agreement is hereby amended and restated in its entirety to read as follows:

provided (i) that any Investment that when made complies with the requirements of the definition of the term “Cash Equivalent Investment” may continue to be held notwithstanding that such Investment if made thereafter would not comply with such requirements; (ii) notwithstanding anything in this Section 9.06 or elsewhere in this Agreement to the contrary, no Investment shall be permitted in any venture or in any Unrestricted Subsidiary, unless, (x) such Investment (other than the

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Specified PGT Contribution) does not include the Disposition of any Collateral (other than cash or Cash Equivalent Investments), and (y) immediately after giving effect to any such Investment, the sum of the borrowing availability under this Agreement plus unrestricted cash and Cash Equivalent Investments of the Borrower and its Restricted Subsidiaries is equal to or greater than fifty percent (50%) of the Aggregate Elected Commitment Amounts, (iii) Investment in the Borrower (or any direct or indirect parent thereof) through redemptions, purchases, acquisitions or other retirements of Equity Interests in the Borrower (or any direct or indirect parent thereof) shall only be permitted to the extent constituting a Restricted Payment permitted by Section 9.08, and (iv) any Investment constituting a Disposition of Properties included in the Borrowing Base or Equity Interests in a Restricted Subsidiary owning Property included in the Borrowing Base shall be subject to Section 9.05(d).

(j)The first sentence of Section 9.23(b) of the Existing Credit Agreement is hereby amended and restated in its entirety to read as follows:

(b) The Borrower may designate by prior written notice thereof to the Administrative Agent, any Restricted Subsidiary, including a newly formed or newly acquired Subsidiary, as an Unrestricted Subsidiary if (i) immediately prior, and after giving effect, to such designation (including any resulting adjustment to the Borrowing Base in accordance with Sections 9.05(d) and 3.04(c)(ii)), (A) the representations and warranties of each Loan Party contained in each of the Loan Documents are true and correct in all material respects (without duplication of any materiality qualification applicable thereto) on and as of such date as if made on and as of the date of such redesignation (or, if stated to have been made expressly as of an earlier date, were true and correct in all material respects (without duplication of any materiality qualification applicable thereto) as of such date), (B) no Event of Default exists or would exist (and the Borrower shall be in compliance, on a pro forma basis, with the covenants set forth in Section 9.01 and, as a condition precedent to the effectiveness of any such designation, the Borrower shall deliver to the Administrative Agent a certificate setting forth in reasonable detail the calculations demonstrating such compliance on a pro forma basis and certifying as to the satisfaction of the other conditions set forth in this Section 9.23(b)), (C) such Subsidiary (1) is not a Material Subsidiary, (2) is not the owner or the operator, by contract or otherwise, of any Oil and Gas Properties included in the Borrowing Base, (3) does not provide gathering, transporting, processing, marketing or other midstream services in respect of the Oil and Gas Properties included in the Borrowing Base and (4) is not a guarantor, “restricted subsidiary” or the primary obligor with respect to any Debt, liabilities or other obligations under any Permitted Debt, the Senior Notes or the Preferred Stock (or any Permitted Refinancing Debt thereof); provided that the foregoing subclauses (C)(1), (C)(2) (solely with respect to the Pinnacle Midstream Assets and not, for the avoidance of doubt, with respect to any Oil and Gas Properties to which oil and gas reserves (including Proved Reserves) are attributable) and (C)(3) shall not apply to the initial designation of PGT or PGS as an Unrestricted Subsidiary in connection with the Specified PGT Contribution; and (D) no Borrowing Base Deficiency would exist; and (ii) the

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Investment deemed to be made in such Subsidiary (and its subsidiaries) pursuant to the next sentence would be permitted to be made at the time of such designation under Section 9.06.

Section 3.Borrowing Base Redetermination. In reliance on the representations, warranties, covenants and agreements contained in this Amendment, the Administrative Agent and the Lenders constituting at least the Required Lenders hereby agree that, effective as of the First Amendment Effective Date, the Borrowing Base shall be reaffirmed at $2,000,000,000, and the Borrowing Base shall remain at $2,000,000,000 until the next Scheduled Redetermination, Interim Redetermination or other adjustment of the Borrowing Base thereafter, whichever occurs first pursuant to the terms of the Credit Agreement. The Borrower and the Lenders constituting at least the Required Lenders acknowledge that (a) the redetermination of the Borrowing Base provided for in this Section 3 shall constitute the Scheduled Redetermination of the Borrowing Base that was scheduled to occur on or about October 1, 2023 for purposes of Section 2.07 of the Credit Agreement and (b) this Amendment constitutes a New Borrowing Base Notice for purposes of Section 2.07(d) of the Credit Agreement with respect to the Borrowing Base redetermination provided for in this Section 3.

Section 4.Ratification. The Borrower, for itself and the other Loan Parties, hereby ratifies and confirms all of the Obligations under the Credit Agreement (as amended hereby) and the other Loan Documents, and in particular, affirms that the terms of the Security Documents secure, and will continue to secure, all Obligations after giving effect to this Amendment.

Section 5.Effectiveness. This Amendment shall become effective upon the first date on which all of the conditions set forth in this Section 5 are satisfied (the “First Amendment Effective Date”):

(a)the Administrative Agent shall have received executed counterpart signature pages to this Amendment from the Borrower, the Administrative Agent and Lenders comprising at least the Required Lenders; and

(b)the Borrower shall have confirmed and acknowledged to the Administrative Agent and the Lenders, and by its execution and delivery of this Amendment, the Borrower does hereby confirm and acknowledge to the Administrative Agent and the Lenders, that (i) the execution, delivery and performance of this Amendment has been duly authorized by all requisite corporate action on the part of the Borrower and each other Loan Party; (ii) the Credit Agreement (as amended hereby) and each other Loan Document constitute valid and legally binding agreements enforceable against the Borrower and each other Loan Party that is a party thereto in accordance with their respective terms, except as such enforceability may be limited by bankruptcy, insolvency, reorganization, moratorium, fraudulent transfer or other similar laws relating to or affecting the enforcement of creditors’ rights generally and by general principles of equity; (iii) the representations and warranties by the Borrower and each other Loan Party contained in the Credit Agreement and in the other Loan Documents are true and correct on and as of the date hereof as though made as of the date hereof; and (iv) no Default or Event of Default exists under the Credit Agreement or any of the other Loan Documents.

-6-

Section 6.Governing Law. This Amendment shall be governed by, and construed in accordance with, the laws of the State of New York.

Section 7.Miscellaneous. (a) On and after the effectiveness of this Amendment, each reference in the Credit Agreement to “this Agreement”, “hereunder”, “hereof” or words of like import referring to the Existing Credit Agreement, and each reference in each other Loan Document to “the Credit Agreement”, “thereunder”, “thereof” or words of like import referring to the Existing Credit Agreement, shall mean and be a reference to the Credit Agreement, as amended or otherwise modified by this Amendment; (b) the execution, delivery and effectiveness of this Amendment shall not, operate as a waiver of any default of the Borrower or any other Loan Party or any right, power or remedy of the Administrative Agent or the Lenders under any of the Loan Documents, nor constitute a waiver of any provision of any of the Loan Documents and except as otherwise modified by the terms hereof, the Credit Agreement and such other Loan Documents shall remain in full force and effect; (c) this Amendment may be executed in any number of counterparts and by different parties hereto in separate counterparts, each of which when so executed shall be deemed to be an original and all of which taken together shall constitute one and the same agreement; and (d) delivery of an executed counterpart of a signature page to this Amendment by telecopier shall be effective as delivery of a manually executed counterpart of this Amendment. This Amendment shall constitute a Loan Document for purposes of the Credit Agreement.

Section 8.Final Agreement. THE CREDIT AGREEMENT AND THE OTHER LOAN DOCUMENTS, INCLUDING THIS AMENDMENT, REPRESENT THE FINAL AGREEMENT BETWEEN THE PARTIES AND MAY NOT BE CONTRADICTED BY EVIDENCE OF PRIOR, CONTEMPORANEOUS OR SUBSEQUENT ORAL AGREEMENTS OF THE PARTIES. THERE ARE NO ORAL AGREEMENTS BETWEEN THE PARTIES.

[Signature Pages Follow]

-7-

IN WITNESS WHEREOF, each of the parties hereto has caused this Amendment to be executed by its officer(s) thereunto duly authorized as of the date first above written.

BORROWER:

COMSTOCK RESOURCES, INC.,
a Nevada corporation

By: /s/ Roland O. Burns

Name: Roland O. Burns

Title: President and Chief Financial Officer

ADMINISTRATIVE AGENT AND LENDERS:

WELLS FARGO BANK, N.A., as Administrative Agent, an Issuing Bank and a Lender

By: /s/ Jonathan Herrick

Name: Jonathan Herrick

Title: Managing Director

BANK OF AMERICA, N.A.,
as a Lender

By: /s/ Christopher Baethge

Name: Christopher Baethge

Title: Vice President

CAPITAL ONE, NATIONAL ASSOCIATION, as a Lender

By: /s/ David Lee Garza

Name: David Lee Garza

Title: Vice President

FIFTH THIRD BANK, NATIONAL ASSOCIATION,
as a Lender

By: /s/ Thomas Kleiderer

Name: Thomas Kleiderer

Title: Managing Director

Mizuho Bank, Ltd.,
as a Lender

By: /s/ Edward Sacks

Name: Edward Sacks

Title: Executive Director

REGIONS BANK,as a Lender

By: /s/ Cody Chance

Name: Cody Chance

Title: Managing Director

TRUIST BANK,as a Lender

By: /s/ Farhan Iqbal

Name: Farhan Iqbal

Title: Director

KEYBANK NATIONAL ASSOCIATION,as a Lender

By: /s/ Eric Appel

Name: Eric Appel

Title: Senior Vice President

PNC BANK, NATIONAL ASSOCIATION,as a Lender

By: /s/ Robert Downey

Name: Robert Downey

Title: Vice President

CITIZENS BANK, N.A.,
as a Lender

By: /s/ Cameron Spence

Name: Cameron Spence

Title: Vice President

CANADIAN IMPERIAL BANK OF COMMERCE, NEW YORK BRANCH,
as a Lender

By: /s/ Jacob W. Lewis

Name: Jacob W. Lewis

Title: Authorized Signatory

By: /s/ Donovan C. Broussard

Name: Donovan C. Broussard

Title: Authorized Signatory

CITIBANK, N.A.,
as a Lender

By: /s/ Jeff Ard

Name: Jeff Ard

Title: Vice President

BARCLAYS BANK PLC,
as a Lender

By: /s/ Sydney G. Dennis

Name: Sydney G. Dennis

Title: Director

FIRST-CITIZENS BANK & TRUST COMPANY,
as a Lender

By: /s/ Jodie Gildersleeve

Name: Jodie Gildersleeve

Title: Vice President

COMERICA BANK,
as a Lender

By: /s/ Cassandra Lucas

Name: Cassandra Lucas

Title: Vice President

GOLDMAN SACHS BANK USA,
as a Lender

By: /s/ Dan Martis

Name: Dan Martis

Title: Authorized Signatory

MORGAN STANLEY SENIOR FUNDING, INC.,
as a Lender

By: /s/ Aaron McLean

Name: Aaron McLean

Title: Vice President

ACKNOWLEDGMENT BY GUARANTORS

Each of the undersigned Guarantors hereby (i) consents to the terms and conditions of that certain First Amendment to Second Amended and Restated Credit Agreement dated effective as of [_], 2023 (the “Amendment”), (ii) acknowledges and agrees that its consent is not required for the effectiveness of the Amendment, (iii) ratifies and acknowledges its respective Obligations under each Loan Document to which it is a party and affirms that the terms of the Guaranty Agreement guarantees, and will continue to guarantee, the Obligations, after giving effect to the Amendment, and (iv) represents and warrants that (a) no Default or Event of Default has occurred and is continuing, (b) it is in full compliance with all covenants and agreements pertaining to it in the Loan Documents, and (c) it has reviewed a copy of the Amendment.

COMSTOCK OIL & GAS, LLC

By Comstock Resources, Inc., its sole member

By: /s/ Roland O. Burns

Name: Roland O. Burns

Title: President

COMSTOCK OIL & GAS – LOUISIANA HOLDINGS, LLC

By Comstock Oil & Gas, LLC, its sole member

By Comstock Resources, Inc., its sole member

By: /s/ Roland O. Burns__________________

Name: Roland O. Burns

Title: President

COMSTOCK OIL & GAS – LOUISIANA, LLC

By: /s/ Roland O. Burns___________________

Name: Roland O. Burns

Title: Manager

By: /s/ M. Jay Allison_____________________

Name: M. Jay Allison

Title: Manager

COMSTOCK GAS SERVICES LLC

By: /s/ Roland O. Burns______________________

Name: Roland O. Burns

Title: President

PINNACLE GAS TREATING LLC

By Comstock Gas Services LLC, its sole member

By: /s/ Roland O. Burns

Name: Roland O. Burns

Title: President

EX-31.1

Exhibit 31.1

Section 302 Certification

I, M. Jay Allison, certify that:

1.I have reviewed this September 30, 2023 Form 10-Q of Comstock Resources, Inc.;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: November 2, 2023
	/s/ M. JAY ALLISON
	Chief Executive Officer

EX-31.2

Exhibit 31.2

Section 302 Certification

I, Roland O. Burns, certify that:

1.I have reviewed this September 30, 2023 Form 10-Q of Comstock Resources, Inc.;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: November 2, 2023
	/s/ ROLAND O. BURNS
	President and Chief Financial Officer

EX-32.1

Exhibit 32.1

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Comstock Resources, Inc. (the “Company”) on Form 10-Q for the three months and nine months ended September 30, 2023 and 2022 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, M. Jay Allison, Chief Executive Officer of the Company, certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to § 906 of the Sarbanes-Oxley Act of 2002, that:

(1)The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)The information contained in the Report fairly presents, in all material respects, the financial condition and result of operations of the Company.

/s/ M. JAY ALLISON

M. Jay Allison

Chief Executive Officer

November 2, 2023

EX-32.2

Exhibit 32.2

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Comstock Resources, Inc. (the “Company”) on Form 10-Q for the three months and nine months ended September 30, 2023 and 2022 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Roland O. Burns, Chief Financial Officer of the Company, certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to § 906 of the Sarbanes-Oxley Act of 2002, that:

(1)The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)The information contained in the Report fairly presents, in all material respects, the financial condition and result of operations of the Company.

/s/ Roland O. Burns

Roland O. Burns

Chief Financial Officer

November 2, 2023

XML

COVER - shares	9 Months Ended
	Sep. 30, 2023	Nov. 01, 2023
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 30, 2023
Document Transition Report	false
Entity File Number	001-03262
Entity Registrant Name	COMSTOCK RESOURCES, INC.
Entity Incorporation, State or Country Code	NV
Entity Tax Identification Number	94-1667468
Entity Address, Address Line One	5300 Town and Country Blvd.
Entity Address, Address Line Two	Suite 500
Entity Address, City or Town	Frisco
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	75034
City Area Code	972
Local Phone Number	668-8800
Title of 12(b) Security	Common Stock, par value $0.50 (per share)
Trading Symbol	CRK
Security Exchange Name	NYSE
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		278,429,463
Amendment Flag	false
Document Fiscal Year Focus	2023
Document Fiscal Period Focus	Q3
Entity Central Index Key	0000023194
Current Fiscal Year End Date	--12-31

XML

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Sep. 30, 2023	Dec. 31, 2022
ASSETS
Cash and cash equivalents	$ 19,835	$ 54,652
Accounts receivable:
Natural gas and oil sales and gas services	157,130	415,079
Joint interest operations	36,506	76,521
From affiliates	21,168	18,527
Derivative financial instruments	23,973	23,884
Other current assets	68,572	56,324
Total current assets	327,184	644,987
Natural gas and oil properties, successful efforts method:
Proved	6,810,440	5,843,409
Unproved	323,666	298,230
Other	48,273	26,475
Accumulated depreciation, depletion and amortization	(1,962,418)	(1,545,459)
Net property and equipment	5,219,961	4,622,655
Goodwill	335,897	335,897
Operating lease right-of-use assets	148,066	90,716
Total assets	6,031,108	5,694,255
LIABILITIES AND STOCKHOLDERS' EQUITY
Accounts payable	503,564	530,195
Accrued costs	103,666	183,111
Operating leases	52,731	38,411
Derivative financial instruments	0	4,420
Total current liabilities	659,961	756,137
Long-term debt	2,503,407	2,152,571
Deferred income taxes	454,612	425,734
Derivative financial instruments	4,540	0
Long-term operating leases	95,397	52,385
Reserve for future abandonment costs	30,434	29,114
Total liabilities	3,748,351	3,415,941
Commitments and contingencies
Stockholders' equity:
Common stock - $0.50 par, 400,000,000 shares authorized, 278,429,463 and 277,517,087 shares issued and outstanding at September 30, 2023 and December 31, 2022, respectively	139,214	138,759
Additional paid-in capital	1,258,069	1,253,417
Accumulated earnings	885,474	886,138
Total stockholders' equity	2,282,757	2,278,314
Total liabilities and stockholders' equity	$ 6,031,108	$ 5,694,255

XML

CONSOLIDATED BALANCE SHEETS (Parenthetical) - $ / shares	Sep. 30, 2023	Dec. 31, 2022
Statement of Financial Position [Abstract]
Common stock, par value (in dollars per share)	$ 0.5	$ 0.5
Common stock, shares authorized (in shares)	400,000,000	400,000,000
Common stock, shares issued (in shares)	278,429,463	277,517,087
Common stock, shares outstanding (in shares)	278,429,463	277,517,087

XML

CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited) - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Revenues:
Total natural gas and oil sales	$ 376,737	$ 1,190,005	$ 1,154,526	$ 2,705,673
Operating expenses:
Production and ad valorem taxes	25,386	24,531	59,891	60,080
Gathering and transportation	47,012	44,740	137,981	113,797
Lease operating	31,664	28,608	100,525	79,873
Exploration	0	0	1,775	3,363
Depreciation, depletion and amortization	148,190	129,065	422,350	354,994
Gas services	67,632	181,818	224,317	305,271
General and administrative	9,586	10,165	31,992	27,451
Loss (gain) on sale of assets	0	0	(125)	(21)
Total operating expenses	329,470	418,927	978,706	944,808
Operating income	47,267	771,078	175,820	1,760,865
Other income (expenses):
Gain (loss) from derivative financial instruments	14,276	(271,335)	76,190	(781,654)
Other income	409	56	1,467	506
Interest expense	(43,624)	(41,393)	(121,082)	(132,204)
Loss on early retirement of debt	0	(0)	0	(46,840)
Total other expenses	(28,939)	(312,672)	(43,425)	(960,192)
Income before income taxes	18,328	458,406	132,395	800,673
Provision for income taxes	(3,608)	(102,810)	(28,878)	(179,610)
Net income	14,720	355,596	103,517	621,063
Preferred stock dividends	0	(4,411)	0	(13,089)
Net income available to common stockholders	$ 14,720	$ 351,185	$ 103,517	$ 607,974
Net income per share:
Basic (in dollars per share)	$ 0.05	$ 1.5	$ 0.37	$ 2.61
Diluted (in dollars per share)	$ 0.05	$ 1.28	$ 0.37	$ 2.24
Weighted average shares outstanding:
Basic (in shares)	276,999	232,482	276,741	232,170
Diluted (in shares)	276,999	277,715	276,741	277,605
Common stock dividends declared (in dollars per share)	$ 0.125	$ 0	$ 0.375	$ 0
Total natural gas and oil sales
Revenues:
Total natural gas and oil sales	$ 305,450	$ 996,915	$ 915,176	$ 2,383,098
Natural gas sales
Revenues:
Total natural gas and oil sales	304,141	994,979	911,065	2,376,774
Oil sales
Revenues:
Total natural gas and oil sales	1,309	1,936	4,111	6,324
Gas services
Revenues:
Total natural gas and oil sales	$ 71,287	$ 193,090	$ 239,350	$ 322,575

XML

CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY (unaudited) - USD ($) shares in Thousands, $ in Thousands	Total	Common Shares	Additional Paid-in Capital	Accumulated Earnings (Deficit)
Beginning balance (in shares) at Dec. 31, 2021		232,925
Beginning balance at Dec. 31, 2021	$ 1,012,779	$ 116,462	$ 1,100,359	$ (204,042)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stock-based compensation (in shares)		(5)
Stock-based compensation	1,477	$ (2)	1,479
Net income (loss)	(111,424)			(111,424)
Payment of preferred stock dividends	(4,315)			(4,315)
Ending balance (in shares) at Mar. 31, 2022		232,920
Ending balance at Mar. 31, 2022	898,517	$ 116,460	1,101,838	(319,781)
Beginning balance (in shares) at Dec. 31, 2021		232,925
Beginning balance at Dec. 31, 2021	1,012,779	$ 116,462	1,100,359	(204,042)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	621,063
Ending balance (in shares) at Sep. 30, 2022		233,758
Ending balance at Sep. 30, 2022	1,619,416	$ 116,879	1,098,605	403,932
Beginning balance (in shares) at Mar. 31, 2022		232,920
Beginning balance at Mar. 31, 2022	898,517	$ 116,460	1,101,838	(319,781)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stock-based compensation (in shares)		239
Stock-based compensation	234	$ 119	115
Net income (loss)	376,891			376,891
Payment of preferred stock dividends	(4,363)			(4,363)
Ending balance (in shares) at Jun. 30, 2022		233,159
Ending balance at Jun. 30, 2022	1,271,279	$ 116,579	1,101,953	52,747
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stock-based compensation (in shares)		599
Stock-based compensation	(3,048)	$ 300	(3,348)
Net income (loss)	355,596			355,596
Payment of preferred stock dividends	(4,411)			(4,411)
Ending balance (in shares) at Sep. 30, 2022		233,758
Ending balance at Sep. 30, 2022	1,619,416	$ 116,879	1,098,605	403,932
Beginning balance (in shares) at Dec. 31, 2022		277,517
Beginning balance at Dec. 31, 2022	2,278,314	$ 138,759	1,253,417	886,138
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stock-based compensation (in shares)		(7)
Stock-based compensation	2,046	$ (4)	2,050
Net income (loss)	134,503			134,503
Payment of common stock dividends	(34,688)			(34,688)
Ending balance (in shares) at Mar. 31, 2023		277,510
Ending balance at Mar. 31, 2023	2,380,175	$ 138,755	1,255,467	985,953
Beginning balance (in shares) at Dec. 31, 2022		277,517
Beginning balance at Dec. 31, 2022	2,278,314	$ 138,759	1,253,417	886,138
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss)	103,517
Ending balance (in shares) at Sep. 30, 2023		278,430
Ending balance at Sep. 30, 2023	2,282,757	$ 139,214	1,258,069	885,474
Beginning balance (in shares) at Mar. 31, 2023		277,510
Beginning balance at Mar. 31, 2023	2,380,175	$ 138,755	1,255,467	985,953
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stock-based compensation (in shares)		983
Stock-based compensation	406	$ 491	(85)
Net income (loss)	(45,706)			(45,706)
Payment of common stock dividends	(34,689)			(34,689)
Ending balance (in shares) at Jun. 30, 2023		278,493
Ending balance at Jun. 30, 2023	2,300,186	$ 139,246	1,255,382	905,558
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Stock-based compensation (in shares)		(63)
Stock-based compensation	2,655	$ (32)	2,687
Net income (loss)	14,720			14,720
Payment of common stock dividends	(34,804)			(34,804)
Ending balance (in shares) at Sep. 30, 2023		278,430
Ending balance at Sep. 30, 2023	$ 2,282,757	$ 139,214	$ 1,258,069	$ 885,474

XML

CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income	$ 103,517	$ 621,063
Adjustments to reconcile net income to net cash provided by operating activities:
Deferred income taxes	28,878	148,389
Gain on sale of assets	(125)	(21)
Depreciation, depletion and amortization	422,350	354,994
(Gain) loss on derivative financial instruments	(76,190)	781,654
Cash settlements of derivative financial instruments	76,221	(679,038)
Amortization of debt discount and issuance costs	5,980	8,542
Stock-based compensation	7,006	4,918
Loss on early retirement of debt	0	46,840
(Increase) decrease in accounts receivable	295,323	(359,600)
(Increase) decrease in other current assets	(624)	359
Increase (decrease) in accounts payable and accrued expenses	(73,697)	301,956
Net cash provided by operating activities	788,639	1,230,056
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital expenditures and acquisitions	(1,088,933)	(768,148)
Prepaid drilling costs	(14,594)	(25,752)
Proceeds from sales of assets	41,295	93
Net cash used for investing activities	(1,062,232)	(793,807)
CASH FLOWS FROM FINANCING ACTIVITIES:
Borrowings on bank credit facility	575,000	705,000
Repayments of bank credit facility	(230,000)	(840,000)
Retirement of Senior Notes	0	(273,920)
Preferred stock dividends paid	0	(13,089)
Common stock dividends paid	(104,181)	0
Debt and stock issuance costs	(144)	0
Income tax withholdings on equity awards	(1,899)	(6,255)
Net cash provided by (used for) financing activities	238,776	(428,264)
Net increase (decrease) in cash and cash equivalents	(34,817)	7,985
Cash and cash equivalents, beginning of period	54,652	30,663
Cash and cash equivalents, end of period	$ 19,835	$ 38,648

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Pay vs Performance Disclosure - USD ($) $ in Thousands	3 Months Ended						9 Months Ended
	Sep. 30, 2023	Jun. 30, 2023	Mar. 31, 2023	Sep. 30, 2022	Jun. 30, 2022	Mar. 31, 2022	Sep. 30, 2023	Sep. 30, 2022
Pay vs Performance Disclosure
Net Income (Loss)	$ 14,720	$ (45,706)	$ 134,503	$ 355,596	$ 376,891	$ (111,424)	$ 103,517	$ 621,063

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Insider Trading Arrangements	3 Months Ended
	Sep. 30, 2023
Trading Arrangements, by Individual
Rule 10b5-1 Arrangement Adopted	false
Non-Rule 10b5-1 Arrangement Adopted	false
Rule 10b5-1 Arrangement Terminated	false
Non-Rule 10b5-1 Arrangement Terminated	false

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

9 Months Ended

Sep. 30, 2023

Accounting Policies [Abstract]

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

(1) SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

Basis of Presentation

These unaudited consolidated financial statements include the accounts of Comstock Resources, Inc. and its wholly-owned subsidiaries (collectively, "Comstock" or the "Company"). In management's opinion, the accompanying unaudited consolidated financial statements contain all adjustments necessary to present fairly the financial position of Comstock as of September 30, 2023, and the related results of operations and cash flows for the periods being presented. Net income and comprehensive income are the same in all periods presented. All adjustments are of a normal recurring nature unless otherwise disclosed.

The accompanying unaudited consolidated financial statements have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission. Certain information and disclosures normally included in annual financial statements prepared in accordance with accounting principles generally accepted in the United States have been omitted pursuant to those rules and regulations, although Comstock believes that the disclosures made are adequate to make the information presented not misleading. These unaudited consolidated financial statements should be read in conjunction with the financial statements and notes thereto included in Comstock's Annual Report on Form 10-K for the year ended December 31, 2022. The results of operations for the period through September 30, 2023 are not necessarily an indication of the results expected for the full year.

Other Current Assets

Other current assets at September 30, 2023 and December 31, 2022 consisted of the following:

	As of
	September 30, 2023		December 31, 2022
	(In thousands)
Pipe and well equipment inventory	$	50,708	$	34,819
Production tax refunds receivable		14,988		11,156
Prepaid expenses		2,876		2,455
Prepaid drilling costs		—		4,265
Accrued proceeds from sale of natural gas and oil properties		—		3,118
Other		—		511
	$	68,572	$	56,324

Property and Equipment

The Company follows the successful efforts method of accounting for its natural gas and oil properties. Costs incurred to acquire natural gas and oil leases and to drill and complete developmental wells are capitalized.

Exploratory well costs are initially capitalized as proved property in the consolidated balance sheets but charged to exploration expense if and when the well is determined not to have found commercial proved natural gas and oil reserves. The changes in capitalized exploratory well costs are as follows:

	Three Months Ended September 30,					Nine Months Ended September 30,
	2023			2022		2023			2022
	(In thousands)
Beginning capitalized exploratory well costs	$	34,196		$	9,771	$	867		$	6,966
Additions to exploratory well costs pending the determination of proved reserves		74,737			20,144		179,049			50,541
Determined to have found proved reserves		(71,838	)		—		(142,821	)		(27,592	)
Ending capitalized exploratory well costs	$	37,095		$	29,915	$	37,095		$	29,915

As of September 30, 2023 and December 31, 2022, the Company had no exploratory wells for which costs have been capitalized for a period greater than one year.

The Company assesses the need for an impairment of the capitalized costs for its proved natural gas and oil properties on a property basis. No impairments were recognized to adjust the carrying value of the Company's proved natural gas and oil properties during any of the periods presented. Unproved natural gas and oil properties are also periodically assessed and any impairment in value is charged to expense. The costs related to unproved properties are transferred to proved natural gas and oil properties and amortized on an equivalent unit-of-production basis when they are reflected in proved natural gas and oil reserves.

The Company determines the fair values of its natural gas and oil properties using a discounted cash flow model and proved and risk-adjusted probable natural gas and oil reserves. Undrilled acreage can also be valued based on sales transactions in comparable areas. Significant Level 3 assumptions associated with the calculation of discounted future cash flows included in the cash flow model include management's outlook for natural gas and oil prices, production costs, capital expenditures, and future production as well as estimated proved natural gas and oil reserves and risk-adjusted probable natural gas and oil reserves. Management's natural gas and oil price outlook is developed based on third-party longer-term price forecasts as of each measurement date. The expected future net cash flows are discounted using an appropriate discount rate in determining a property's fair value.

It is reasonably possible that the Company's estimates of undiscounted future net cash flows attributable to its natural gas and oil properties may change in the future. The primary factors that may affect estimates of future cash flows include future adjustments, both positive and negative, to proved and appropriate risk-adjusted probable natural gas and oil reserves, results of future drilling activities, future prices for natural gas and oil, and increases or decreases in production and capital costs. As a result of these changes, there may be future impairments in the carrying values of these or other properties.

Goodwill

The Company had goodwill of $335.9 million as of September 30, 2023 that was recorded in 2018. The Company is not required to amortize goodwill as a charge to earnings; however, the Company is required to conduct an annual review of goodwill for impairment. The Company performs an annual assessment of goodwill on October 1 of each year and performs interim assessments if indicators of impairment are present. If the carrying value of goodwill exceeds the fair value, an impairment charge would be recorded for the difference between fair value and carrying value.

Leases

The Company has right-of-use lease assets of $148.1 million related to its corporate office, certain office equipment, vehicles, drilling rigs and hydraulic fracturing fleets with corresponding short-term and long-term liabilities. The value of the lease assets and liabilities are determined based upon discounted future minimum cash flows contained within each of the respective contracts. The Company determines if contracts contain a lease at inception of the contract. To the extent that contract terms representing a lease are identified, leases are identified as being either an operating lease or a finance-type lease. Comstock currently has no finance-type leases. Right-of-use lease assets representing the Company's right to use an underlying asset for the lease term and the related lease liabilities represent our obligation to make lease payments under the terms of the contracts. Short-term leases that have an initial term of one year or less are not capitalized; however, amounts paid for those leases are included as part of its lease cost disclosures. Short-term lease costs exclude expenses related to leases with a lease term of one month or less. Leases for the right to explore for and develop natural gas and oil reserves and the related rights to use the land associated with those leases are reflected as natural gas and oil properties.

Comstock contracts for a variety of equipment used in its natural gas and oil exploration and development activities. Contract terms for this equipment vary broadly, including the contract duration, pricing, scope of services included along with the equipment, cancellation terms, and rights of substitution, among others. The Company's drilling and completion operations routinely change due to changes in commodity prices, demand for natural gas and oil, and the overall operating and economic environment. Accordingly, Comstock manages the terms of its contracts for drilling rigs and completion equipment so as to allow for maximum flexibility in responding to these changing conditions. The Company has one hydraulic fracturing fleet lease contract with a three year term. The Company's other hydraulic fracturing fleet contracts are on terms less than one year and include rights of substitution. The Company has one drilling rig contract with a three year term. The Company's other drilling rig contracts are presently either for periods of less than one year, or they are on terms that provide for cancellation with 45 days advance notice without a specified expiration date. The Company has elected not to recognize right-of-use lease assets for contracts less than one year. The costs associated with drilling and completion operations are accounted for under the successful efforts method, which generally require that these costs be capitalized as part of our proved natural gas and oil properties on our balance sheet unless they are incurred on exploration wells that are unsuccessful, in which case they are charged to exploration expense.

Lease costs recognized during the three months and nine months ended September 30, 2023 and 2022 were as follows:

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
	(In thousands)
Operating lease cost included in general and administrative expense	$	445	$	436	$	1,334	$	1,307
Operating lease cost included in lease operating expense		523		370		1,533		970
Operating lease cost included in natural gas and oil properties		18,659		9,450		41,339		15,750
Variable lease cost (completion costs included in natural gas and oil properties)		25,970		11,730		31,032		22,857
Short-term lease cost (drilling rig costs included in natural gas and oil properties)		20,098		16,102		73,986		44,242
	$	65,695	$	38,088	$	149,224	$	85,126

Cash payments for operating leases associated with right-of-use assets included in cash provided by operating activities were $1.0 million and $0.8 million for the three months ended September 30, 2023 and 2022, respectively, and $2.9 million and $2.3 million for the nine months ended September 30, 2023 and 2022, respectively. Cash payments for operating leases associated with right-of-use assets included in cash used for investing activities were $64.7 million and $37.3 million for the three months ended September 30, 2023 and 2022, respectively and $146.4 million and $82.8 million for the nine months ended September 30, 2023 and 2022, respectively.

As of September 30, 2023 and December 31, 2022, the operating leases had a weighted-average term of 2.6 years and 2.2 years, respectively, and the weighted-average discount rate used to determine the present value of future operating lease payments was 6.9% and 3.5%, respectively. As of September 30, 2023, the Company also had expected future payments for short term leased drilling services of $7.0 million.

As of September 30, 2023, expected future payments related to contracts that contain operating leases were as follows:

	(In thousands)
October 1 to December 31, 2023	$	15,291
2024		61,302
2025		58,919
2026		27,374
2027		17
Total lease payments		162,903
Imputed interest		(14,775	)
Total lease liability	$	148,128

Accrued Costs

Accrued costs at September 30, 2023 and December 31, 2022 consisted of the following:

	As of
	September 30, 2023		December 31, 2022
	(In thousands)
Accrued transportation costs	$	32,731	$	28,357
Accrued drilling costs		21,997		54,438
Accrued interest payable		19,730		54,867
Accrued income and other taxes		18,212		31,256
Accrued employee compensation		7,350		11,308
Accrued lease operating expenses		2,949		2,412
Other		697		473
	$	103,666	$	183,111

Reserve for Future Abandonment Costs

Comstock's asset retirement obligations relate to future plugging and abandonment expenses on its natural gas and oil properties and disposal of other facilities. The following table summarizes the changes in Comstock's total estimated liability for such obligations during the periods presented:

	Nine Months Ended September 30,
	2023			2022
	(In thousands)
Reserve for future abandonment costs at beginning of period	$	29,114		$	25,673
New wells placed on production		114			1,251
Acquisitions		—			1,211
Liabilities settled and assets disposed of		(42	)		(29	)
Accretion expense		1,248			1,129
Reserve for future abandonment costs at end of period	$	30,434		$	29,235

Derivative Financial Instruments and Hedging Activities

All of the Company's derivative financial instruments are used for risk management purposes and, by policy, none are held for trading or speculative purposes. Comstock minimizes credit risk to counterparties of its derivative financial instruments through formal credit policies, monitoring procedures, and diversification. The Company is not required to provide any credit support to its counterparties other than cross collateralization with the assets securing its bank credit facility. None of the Company's derivative financial instruments involve payment or receipt of premiums. The Company classifies the fair value amounts of derivative financial instruments as net current or noncurrent assets or liabilities, whichever the case may be, by commodity contract. None of the Company's derivative contracts were designated as cash flow hedges. All of Comstock's natural gas derivative financial instruments are tied to the Henry Hub-NYMEX price index.

The Company had the following natural gas price derivative financial instruments at September 30, 2023:

	Future Production Period
	Three Months Ending December 31, 2023		Year Ending December 31, 2024		Total
Natural Gas Price Swap Contracts:
Volume (MMBtu)		—		91,500,000		91,500,000
Average Price per MMBtu			$	3.55	$	3.55
Natural Gas Price Collar Contracts:
Volume (MMBtu)		23,000,000				23,000,000
Average Price per MMBtu:
Average Ceiling	$	10.28			$	10.28
Average Floor	$	3.00			$	3.00

Subsequent to September 30, 2023, the Company entered into natural gas swap contracts to hedge an additional 47,580,000 MMBtu of natural gas production from January 2024 to December 2024 at an average price of $3.56 per MMBtu.

The classification of derivative financial instruments of assets or liabilities, consists of the following:

		As of
Type	Consolidated Balance Sheet Location	September 30, 2023		December 31, 2022
		(In thousands)
Asset Derivative Financial Instruments:
Natural gas price derivatives	Derivative Financial Instruments – current	$	23,973	$	23,884
		$	23,973	$	23,884
Liability Derivative Financial Instruments:
Natural gas price derivatives	Derivative Financial Instruments – current	$	—	$	4,420
		$	—	$	4,420
Natural gas price derivatives	Derivative Financial Instruments – long-term	$	4,540	$	—
		$	4,540	$	—

The Company recognized cash settlements and changes in the fair value of its derivative financial instruments as a single component of other income (expenses). Gains and losses related to cash settlements and changes in the fair value recognized on the Company's derivative contracts recognized in the consolidated statement of operations were as follows:

	Three Months Ended September 30,					Nine Months Ended September 30,
Gain (Loss) on Derivatives Recognized in Earnings	2023		2022			2023		2022
	(In thousands)
Natural gas price derivatives	$	14,276	$	(271,335	)	$	76,190	$	(781,654	)
	$	14,276	$	(271,335	)	$	76,190	$	(781,654	)

Stock-Based Compensation

Comstock accounts for employee stock-based compensation under the fair value method. Compensation cost is measured at the grant date based on the fair value of the award and is recognized over the award vesting period and included in general and administrative expenses for awards of restricted stock and performance stock units ("PSUs") to the Company's employees and directors. The Company recognized $2.7 million and $1.8 million of stock-based compensation expense within general and administrative expenses related to awards of restricted stock and PSUs to its employees and directors during the three months ended September 30, 2023 and 2022, respectively, and $7.0 million and $4.9 million for the nine months ended September 30, 2023 and 2022, respectively.

In June 2023, the Company granted an aggregate of 954,031 shares of restricted stock to its directors and employees. The grants were valued at $9.80 per share. As of September 30, 2023, Comstock had 1,430,949 shares of unvested restricted stock outstanding at a weighted average grant date fair value of $11.62 per share. Total unrecognized compensation cost related to unvested restricted stock grants of $14.3 million as of September 30, 2023 is expected to be recognized over a period of 2.2 years.

In June 2023, the Company granted an aggregate of 359,689 PSUs to its executive officers at a value of $13.64 per unit. As of September 30, 2023, Comstock had 750,399 PSUs outstanding with a weighted average grant date fair value of $15.92 per unit. The number of shares of common stock to be issued related to the PSUs is based on the Company's stock price performance as compared to its peers which could result in the issuance of anywhere from zero to 1,500,798 shares of common stock. Total unrecognized compensation cost related to these grants of $7.9 million as of September 30, 2023 is expected to be recognized over a period of 2.3 years.

Revenue Recognition

Comstock produces natural gas and oil and reports revenues separately for each of these two primary products in its statements of operations. Revenues are recognized upon the transfer of produced volumes to the Company's customers, who take control of the volumes and receive all the benefits of ownership upon delivery at designated sales points.

Gas services revenues represent sales of natural gas purchased for resale from unaffiliated third parties and fees received for gathering and treating services for certain natural gas wells operated by the Company. Revenues are recognized upon completion of the gathering and treating of contracted natural gas volumes and delivery of purchased natural gas volumes to the Company's customers. Profits and losses earned in the gathering and treating of natural gas produced by the Company's natural gas wells are eliminated in consolidation. Revenues and expenses associated with natural gas purchased for resale are presented on a gross basis in the Company's consolidated statements of operations as the Company acts as the principal in the transaction by assuming the risks and rewards from ownership of the natural gas volumes purchased and the responsibility to deliver the natural gas volumes to their sales point.

All natural gas and oil and gas services revenues are subject to contracts that have commercial substance, contain specific pricing terms, and define the enforceable rights and obligations of both parties. These contracts typically provide for cash settlement within 25 days following each production month and are cancellable upon 30 days' notice by either party for oil and vary for natural gas based upon the terms set out in the confirmations between both parties. Prices for sales of natural gas and oil are generally based upon terms that are common in the oil and gas industry, including index or spot prices, location and quality differentials, as well as market supply and demand conditions. As a result, prices for natural gas and oil routinely fluctuate based on changes in these factors. Prices for gathering and treating services are generally fixed in nature but can vary due to the quality of the gas being treated. Each unit of production (barrel of crude oil and thousand cubic feet of natural gas) represents a separate performance obligation under the Company's contracts since each unit has economic benefit on its own and each is priced separately according to the terms of the contracts.

Comstock has elected to exclude all taxes from the measurement of transaction prices, and its revenues are reported net of royalties and exclude revenue interests owned by others because the Company acts as an agent when selling natural gas and oil, on behalf of royalty owners and working interest owners. Revenue is recorded in the month of production based on an estimate of the Company's share of volumes produced and prices realized. Gas services revenue is recorded in the month the services are performed and purchased gas is sold based on an estimate of natural gas volumes and contract prices. The Company recognizes any differences between estimates and actual amounts received in the month when payment is received. Historically, differences between estimated revenues and actual revenue received have not been significant. The amount of natural gas or oil sold may differ from the amount to which the Company is entitled based on its revenue interests in the properties. The Company did not have any significant imbalance positions at September 30, 2023 or December 31, 2022.

The Company recognized accounts receivable of $157.1 million and $415.1 million as of September 30, 2023 and December 31, 2022, respectively, from purchasers for contracts where performance obligations have been satisfied and an unconditional right to consideration exists.

Credit Losses

Substantially all of the Company's accounts receivable are due from either purchasers of natural gas and oil or participants in natural gas and oil wells for which the Company serves as the operator. Generally, operators of natural gas and oil wells have the right to offset future revenues against unpaid charges related to operated wells. Natural gas and oil sales are generally unsecured. Comstock assesses the collectability of its receivables based upon their age, the credit quality of the purchaser or participant and the potential for revenue offset. The Company has not had any significant credit losses in the past and believes its accounts receivable are fully collectible. Accordingly, no allowance for doubtful accounts has been recorded for the nine months ended September 30, 2023 and 2022.

Income Taxes

Deferred income taxes are provided to reflect the future tax consequences or benefits of differences between the tax basis of assets and liabilities and their reported amounts in the financial statements using enacted tax rates.

In recording deferred income tax assets, the Company considers whether it is more likely than not that its deferred income tax assets will be realized in the future. The ultimate realization of deferred income tax assets is dependent upon the generation of future taxable income during the periods in which those deferred income tax assets would be deductible. The Company believes that after considering all the available objective evidence, historical and prospective, with greater weight given to historical evidence, management is not able to determine that it is more likely than not that all of its deferred tax assets will be realized. As a result, the Company established valuation allowances for its deferred tax assets and U.S. federal and state net operating loss carryforwards that are not expected to be utilized due to the uncertainty of generating taxable income prior to the expiration of the carryforward periods. The Company will continue to assess the valuation allowances against deferred tax assets considering all available information obtained in future periods.

The following is an analysis of the consolidated income tax provision (benefit):

	Three Months Ended September 30,					Nine Months Ended September 30,
	2023			2022		2023		2022
	(In thousands)
Current - Federal	$	—		$	10,001	$	—	$	11,400
Current - State		—			14,749		—		19,821
Deferred - Federal		3,999			66,732		28,350		124,600
Deferred - State		(391	)		11,328		528		23,789
	$	3,608		$	102,810	$	28,878	$	179,610

The difference between the federal statutory rate of 21% and the effective tax rate is due to the following:

	Three Months Ended September 30,						Nine Months Ended September 30,
	2023			2022			2023			2022
Tax at statutory rate		21.0	%		21.0	%		21.0	%		21.0	%
Tax effect of:
Valuation allowance on deferred tax assets		5.5			(4.1	)		1.7			(4.0	)
State income taxes, net of federal benefit		(8.2	)		5.8			(1.6	)		5.6
Nondeductible stock-based compensation		1.7			(0.2	)		0.8			(0.1	)
Other		(0.3	)		(0.1	)		(0.1	)		—
Effective tax rate		19.7	%		22.4	%		21.8	%		22.5	%

The Company's federal income tax returns for the years subsequent to December 31, 2018 remain subject to examination. The Company's income tax returns in major state income tax jurisdictions remain subject to examination for various periods subsequent to December 31, 2019. The Company is currently under examination with the state of Louisiana and believes that its significant filing positions are highly certain and that all of its other significant income tax filing positions and deductions would be sustained under audit or the final resolution would not have a material effect on the consolidated financial statements. Therefore, the Company has not established any significant reserves for uncertain tax positions.

Fair Value Measurements

The Company holds or has held certain financial assets and liabilities that are required to be measured at fair value. These include cash and cash equivalents held in bank accounts and derivative financial instruments. Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants on the measurement date. A three-level hierarchy is followed for disclosure to show the extent and level of judgment used to estimate fair value measurements:

Level 1 — Inputs used to measure fair value are unadjusted quoted prices that are available in active markets for the identical assets or liabilities as of the reporting date.

Level 2 — Inputs used to measure fair value, other than quoted prices included in Level 1, are either directly or indirectly observable as of the reporting date through correlation with market data, including quoted prices for similar assets and liabilities in active markets and quoted prices in markets that are not active. Level 2 also includes assets and liabilities that are valued using models or other pricing methodologies that do not require significant judgment since the input assumptions used in the models, such as interest rates and volatility factors, are corroborated by readily observable data from actively quoted markets for substantially the full term of the financial instrument.

Level 3 — Inputs used to measure fair value are unobservable inputs that are supported by little or no market activity and reflect the use of significant management judgment. These values are generally determined using pricing models for which the assumptions utilize management's estimates of market participant assumptions.

Fair Values – Reported

The following presents the carrying amounts and the fair values of the Company's financial instruments as of September 30, 2023 and December 31, 2022:

	As of
	September 30, 2023				December 31, 2022
	Carrying Value		Fair Value		Carrying Value		Fair Value
	(In thousands)
Assets:
Commodity-based derivatives (1)	$	23,973	$	23,973	$	23,884	$	23,884
Liabilities:
Commodity-based derivatives (1)	$	4,540	$	4,540	$	4,420	$	4,420
Bank credit facility (2)	$	345,000	$	345,000	$	—	$	—
6.75% senior notes due 2029 (3)	$	1,229,230	$	1,116,791	$	1,229,836	$	1,129,029
5.875% senior notes due 2030 (3)	$	965,000	$	829,900	$	965,000	$	846,788

(1)The Company's commodity-based derivatives are classified as Level 2 and measured at fair value using third party pricing services and other active markets or broker quotes that are readily available in the public markets.

(2)The carrying value of our floating rate debt outstanding approximates fair value.

(3)The fair value of the Company's fixed rate debt was based on quoted prices as of September 30, 2023 and December 31, 2022, respectively, a Level 1 measurement.

Earnings Per Share

Unvested restricted stock containing non-forfeitable rights to dividends are included in common stock outstanding and are considered to be participating securities and included in the computation of basic and diluted earnings per share pursuant to the two-class method. At September 30, 2023 and December 31, 2022, 1,430,949 and 966,058 shares of restricted stock, respectively, are included in common stock outstanding as such shares have a non-forfeitable right to participate in any dividends that might be declared and have the right to vote on matters submitted to the Company's stockholders.

Weighted average shares of unvested restricted stock outstanding were as follows:

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
	(In thousands)
Unvested restricted stock		1,469		890		1,186		914

PSUs represent the right to receive a number of shares of the Company's common stock that may range from zero to up to two times the number of PSUs granted on the award date based on the achievement of certain performance measures during a performance period. The number of potentially dilutive shares related to PSUs is based on the number of shares, if any, which would be issuable at the end of the respective period, assuming that date was the end of the performance period. The treasury stock method is used to measure the dilutive effect of PSUs.

Weighted average unearned PSUs outstanding were as follows:

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
	(In thousands, except per unit amounts)
Weighted average PSUs		744		942		631		1,024
Weighted average grant date fair value per unit	$	15.92	$	14.52	$	15.92	$	14.52

Basic and diluted income (loss) per share for the three months and nine months ended September 30, 2023 and 2022 were determined as follows:

	Three Months Ended September 30,
	2023						2022
	Income		Shares		Per Share		Loss			Shares		Per Share
	(In thousands, except per share amounts)
Net income attributable to common stock	$	14,720					$	351,185
Income allocable to unvested restricted shares		—						(1,339	)
Basic income attributable to common stock		14,720		276,999	$	0.05		349,846			232,482	$	1.50
Effect of Dilutive Securities:
Restricted stock		—		—				1,339			392
Performance stock units		—		—				—			1,091
Convertible preferred stock		—		—				4,411			43,750
Diluted income attributable to common stock	$	14,720		276,999	$	0.05	$	355,596			277,715	$	1.28

	Nine Months Ended September 30,
	2023						2022
	Income		Shares		Per Share		Loss			Shares		Per Share
	(In thousands, except per share amounts)
Net income attributable to common stock	$	103,517					$	607,974
Income allocable to unvested restricted shares		—						(2,384	)
Basic income attributable to common stock		103,517		276,741	$	0.37		605,590			232,170	$	2.61
Effect of Dilutive Securities:
Restricted stock		—		—				2,384			541
Performance stock units		—		—				—			1,144
Convertible preferred stock		—		—				13,089			43,750
Diluted income attributable to common stock	$	103,517		276,741	$	0.37	$	621,063			277,605	$	2.24

None of the Company's participating securities participate in losses and as such are excluded from the computation of basic earnings per share during periods of net losses.

Supplementary Information with Respect to the Consolidated Statements of Cash Flows

Cash payments made for interest and income taxes and other non-cash investing activities for the nine months ended September 30, 2023 and 2022, respectively, were as follows:

	Nine Months Ended September 30,
	2023			2022
	(In thousands)
Cash payments for:
Interest payments	$	150,239		$	164,106
Income tax payments	$	29,796		$	719
Non-cash investing activities include:
Increase (decrease) in accrued capital expenditures	$	(32,441	)	$	16,202
Liabilities assumed in exchange for right-of-use lease assets	$	157,789		$	109,546

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LONG-TERM DEBT

9 Months Ended

Sep. 30, 2023

Debt Disclosure [Abstract]

LONG-TERM DEBT

(2) LONG-TERM DEBT

At September 30, 2023, long-term debt was comprised of the following:

	(In thousands)
6.75% Senior Notes due 2029:
Principal	$	1,223,880
Premium, net of amortization		5,350
5.875% Senior Notes due 2030:
Principal		965,000
Bank Credit Facility:
Principal		345,000
Debt issuance costs, net of amortization		(35,823	)
	$	2,503,407

As of September 30, 2023, the Company had $345.0 million outstanding under a bank credit facility. Aggregate commitments under the bank credit facility are $1.5 billion, which matures on November 15, 2027. Borrowings under the bank credit facility are subject to a borrowing base, which is currently set at $2.0 billion. The borrowing base is re-determined on a semi-annual basis and upon the occurrence of certain other events. Borrowings under the bank credit facility are secured by substantially all of the assets of the Company and its subsidiaries and bear interest at the Company's option, at either SOFR plus 1.75% to 2.75% or an alternate base rate plus 0.75% to 1.75%, in each case depending on the utilization of the borrowing base. The Company also pays a commitment fee of 0.375% to 0.5% on the unused portion of the borrowing base. The bank credit facility places certain restrictions upon the Company's and its subsidiaries' ability to, among other things, incur additional indebtedness, pay cash dividends, repurchase common stock, make certain loans, investments and divestitures and redeem the senior notes. The only financial covenants are the maintenance of a leverage ratio of less than 3.5 to 1.0 and an adjusted current ratio of at least 1.0 to 1.0. The Company was in compliance with the covenants as of September 30, 2023.

During the nine months ended September 30, 2022, the Company completed the early redemption of all of its outstanding 7.5% senior notes due in 2025 for an aggregate amount of $258.1 million and repurchased $26.1 million principal amount of its 6.75% senior notes due in 2029 for $24.9 million. As a result of the redemption and repurchase, the Company recognized a loss of $46.8 million on early retirement of debt.

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COMMITMENTS AND CONTINGENCIES

9 Months Ended

Sep. 30, 2023

Commitments and Contingencies Disclosure [Abstract]

COMMITMENTS AND CONTINGENCIES

(3) COMMITMENTS AND CONTINGENCIES

In December 2022, the Company entered into agreements for three new drilling rigs with a three year term and a minimum annual commitment of $12.2 million per drilling rig. Comstock took delivery of one of the rigs during August 2023 and expects to take delivery of the second rig in the fourth quarter of 2023 and the third rig in early 2024.

From time to time, the Company is involved in certain litigation that arises in the normal course of its operations. The Company records a loss contingency for these matters when it is probable that a liability has been incurred and the amount of the loss can be reasonably estimated. The Company does not believe the resolution of these matters will have a material effect on the Company's financial position, results of operations or cash flows and no material amounts are accrued relative to these matters at September 30, 2023 or 2022.

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RELATED PARTY TRANSACTIONS

9 Months Ended

Sep. 30, 2023

Related Party Transactions [Abstract]

RELATED PARTY TRANSACTIONS

(4) RELATED PARTY TRANSACTIONS

Comstock operates natural gas and oil properties held by partnerships owned by its majority stockholder. The Company charges the partnerships for the costs incurred to drill, complete and produce wells, as well as drilling and operating overhead fees. Comstock also provides natural gas marketing services to the partnerships, including evaluating potential markets and providing hedging services, in return for a fee equal to $0.02 per Mcf for natural gas marketed. The Company received $327 thousand and $152 thousand for the three months ended September 30, 2023 and 2022, respectively, and $1.0 million and $735 thousand for the nine months ended September 30, 2023 and 2022, respectively, for drilling, operating and marketing services provided to the partnerships. The fees received for the services are reflected as a reduction of general and administrative expenses in the accompanying consolidated statements of operations.

In connection with the operation of the wells, the Company had a $21.2 million and $18.5 million receivable from the partnerships at September 30, 2023 and December 31, 2022, respectively.

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SUBSEQUENT EVENT

9 Months Ended

Sep. 30, 2023

Subsequent Events [Abstract]

SUBSEQUENT EVENT

(5) SUBSEQUENT EVENT

On October 30, 2023, the board of directors of the Company authorized a dividend of $0.125 per share to be paid on December 15, 2023 to common stockholders of record on December 1, 2023.

On October 30, 2023, Comstock entered into a midstream partnership for the Company's Western Haynesville acreage with Quantum Capital Solutions ("QCS"), an affiliate of Quantum Capital Group. In connection with this transaction, Comstock contributed its Pinnacle gathering and treating system, which is comprised of a 145-mile high pressure pipeline and the Bethel natural gas processing plant to the partnership in exchange for a total capital commitment by QCS of $300 million to fund the future build-out of the Western Haynesville midstream system. Comstock will control and operate the midstream system.

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)

9 Months Ended

Sep. 30, 2023

Accounting Policies [Abstract]

Basis of Presentation

Basis of Presentation

These unaudited consolidated financial statements include the accounts of Comstock Resources, Inc. and its wholly-owned subsidiaries (collectively, "Comstock" or the "Company"). In management's opinion, the accompanying unaudited consolidated financial statements contain all adjustments necessary to present fairly the financial position of Comstock as of September 30, 2023, and the related results of operations and cash flows for the periods being presented. Net income and comprehensive income are the same in all periods presented. All adjustments are of a normal recurring nature unless otherwise disclosed.

The accompanying unaudited consolidated financial statements have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission. Certain information and disclosures normally included in annual financial statements prepared in accordance with accounting principles generally accepted in the United States have been omitted pursuant to those rules and regulations, although Comstock believes that the disclosures made are adequate to make the information presented not misleading. These unaudited consolidated financial statements should be read in conjunction with the financial statements and notes thereto included in Comstock's Annual Report on Form 10-K for the year ended December 31, 2022. The results of operations for the period through September 30, 2023 are not necessarily an indication of the results expected for the full year.

Property and Equipment

Property and Equipment

The Company follows the successful efforts method of accounting for its natural gas and oil properties. Costs incurred to acquire natural gas and oil leases and to drill and complete developmental wells are capitalized.

Exploratory well costs are initially capitalized as proved property in the consolidated balance sheets but charged to exploration expense if and when the well is determined not to have found commercial proved natural gas and oil reserves. The changes in capitalized exploratory well costs are as follows:

	Three Months Ended September 30,					Nine Months Ended September 30,
	2023			2022		2023			2022
	(In thousands)
Beginning capitalized exploratory well costs	$	34,196		$	9,771	$	867		$	6,966
Additions to exploratory well costs pending the determination of proved reserves		74,737			20,144		179,049			50,541
Determined to have found proved reserves		(71,838	)		—		(142,821	)		(27,592	)
Ending capitalized exploratory well costs	$	37,095		$	29,915	$	37,095		$	29,915

As of September 30, 2023 and December 31, 2022, the Company had no exploratory wells for which costs have been capitalized for a period greater than one year.

The Company assesses the need for an impairment of the capitalized costs for its proved natural gas and oil properties on a property basis. No impairments were recognized to adjust the carrying value of the Company's proved natural gas and oil properties during any of the periods presented. Unproved natural gas and oil properties are also periodically assessed and any impairment in value is charged to expense. The costs related to unproved properties are transferred to proved natural gas and oil properties and amortized on an equivalent unit-of-production basis when they are reflected in proved natural gas and oil reserves.

The Company determines the fair values of its natural gas and oil properties using a discounted cash flow model and proved and risk-adjusted probable natural gas and oil reserves. Undrilled acreage can also be valued based on sales transactions in comparable areas. Significant Level 3 assumptions associated with the calculation of discounted future cash flows included in the cash flow model include management's outlook for natural gas and oil prices, production costs, capital expenditures, and future production as well as estimated proved natural gas and oil reserves and risk-adjusted probable natural gas and oil reserves. Management's natural gas and oil price outlook is developed based on third-party longer-term price forecasts as of each measurement date. The expected future net cash flows are discounted using an appropriate discount rate in determining a property's fair value.

It is reasonably possible that the Company's estimates of undiscounted future net cash flows attributable to its natural gas and oil properties may change in the future. The primary factors that may affect estimates of future cash flows include future adjustments, both positive and negative, to proved and appropriate risk-adjusted probable natural gas and oil reserves, results of future drilling activities, future prices for natural gas and oil, and increases or decreases in production and capital costs. As a result of these changes, there may be future impairments in the carrying values of these or other properties.

Goodwill

Goodwill

The Company had goodwill of $335.9 million as of September 30, 2023 that was recorded in 2018. The Company is not required to amortize goodwill as a charge to earnings; however, the Company is required to conduct an annual review of goodwill for impairment. The Company performs an annual assessment of goodwill on October 1 of each year and performs interim assessments if indicators of impairment are present. If the carrying value of goodwill exceeds the fair value, an impairment charge would be recorded for the difference between fair value and carrying value.

Leases

Leases

The Company has right-of-use lease assets of $148.1 million related to its corporate office, certain office equipment, vehicles, drilling rigs and hydraulic fracturing fleets with corresponding short-term and long-term liabilities. The value of the lease assets and liabilities are determined based upon discounted future minimum cash flows contained within each of the respective contracts. The Company determines if contracts contain a lease at inception of the contract. To the extent that contract terms representing a lease are identified, leases are identified as being either an operating lease or a finance-type lease. Comstock currently has no finance-type leases. Right-of-use lease assets representing the Company's right to use an underlying asset for the lease term and the related lease liabilities represent our obligation to make lease payments under the terms of the contracts. Short-term leases that have an initial term of one year or less are not capitalized; however, amounts paid for those leases are included as part of its lease cost disclosures. Short-term lease costs exclude expenses related to leases with a lease term of one month or less. Leases for the right to explore for and develop natural gas and oil reserves and the related rights to use the land associated with those leases are reflected as natural gas and oil properties.

Comstock contracts for a variety of equipment used in its natural gas and oil exploration and development activities. Contract terms for this equipment vary broadly, including the contract duration, pricing, scope of services included along with the equipment, cancellation terms, and rights of substitution, among others. The Company's drilling and completion operations routinely change due to changes in commodity prices, demand for natural gas and oil, and the overall operating and economic environment. Accordingly, Comstock manages the terms of its contracts for drilling rigs and completion equipment so as to allow for maximum flexibility in responding to these changing conditions. The Company has one hydraulic fracturing fleet lease contract with a three year term. The Company's other hydraulic fracturing fleet contracts are on terms less than one year and include rights of substitution. The Company has one drilling rig contract with a three year term. The Company's other drilling rig contracts are presently either for periods of less than one year, or they are on terms that provide for cancellation with 45 days advance notice without a specified expiration date. The Company has elected not to recognize right-of-use lease assets for contracts less than one year. The costs associated with drilling and completion operations are accounted for under the successful efforts method, which generally require that these costs be capitalized as part of our proved natural gas and oil properties on our balance sheet unless they are incurred on exploration wells that are unsuccessful, in which case they are charged to exploration expense.

Reserve for Future Abandonment Costs

Reserve for Future Abandonment Costs

Comstock's asset retirement obligations relate to future plugging and abandonment expenses on its natural gas and oil properties and disposal of other facilities.

Derivative Financial Instruments and Hedging Activities

Derivative Financial Instruments and Hedging Activities

All of the Company's derivative financial instruments are used for risk management purposes and, by policy, none are held for trading or speculative purposes. Comstock minimizes credit risk to counterparties of its derivative financial instruments through formal credit policies, monitoring procedures, and diversification. The Company is not required to provide any credit support to its counterparties other than cross collateralization with the assets securing its bank credit facility. None of the Company's derivative financial instruments involve payment or receipt of premiums. The Company classifies the fair value amounts of derivative financial instruments as net current or noncurrent assets or liabilities, whichever the case may be, by commodity contract. None of the Company's derivative contracts were designated as cash flow hedges. All of Comstock's natural gas derivative financial instruments are tied to the Henry Hub-NYMEX price index.

Stock-Based Compensation

Stock-Based Compensation

Comstock accounts for employee stock-based compensation under the fair value method. Compensation cost is measured at the grant date based on the fair value of the award and is recognized over the award vesting period and included in general and administrative expenses for awards of restricted stock and performance stock units ("PSUs") to the Company's employees and directors.

Revenue Recognition

Revenue Recognition

Comstock produces natural gas and oil and reports revenues separately for each of these two primary products in its statements of operations. Revenues are recognized upon the transfer of produced volumes to the Company's customers, who take control of the volumes and receive all the benefits of ownership upon delivery at designated sales points.

Gas services revenues represent sales of natural gas purchased for resale from unaffiliated third parties and fees received for gathering and treating services for certain natural gas wells operated by the Company. Revenues are recognized upon completion of the gathering and treating of contracted natural gas volumes and delivery of purchased natural gas volumes to the Company's customers. Profits and losses earned in the gathering and treating of natural gas produced by the Company's natural gas wells are eliminated in consolidation. Revenues and expenses associated with natural gas purchased for resale are presented on a gross basis in the Company's consolidated statements of operations as the Company acts as the principal in the transaction by assuming the risks and rewards from ownership of the natural gas volumes purchased and the responsibility to deliver the natural gas volumes to their sales point.

All natural gas and oil and gas services revenues are subject to contracts that have commercial substance, contain specific pricing terms, and define the enforceable rights and obligations of both parties. These contracts typically provide for cash settlement within 25 days following each production month and are cancellable upon 30 days' notice by either party for oil and vary for natural gas based upon the terms set out in the confirmations between both parties. Prices for sales of natural gas and oil are generally based upon terms that are common in the oil and gas industry, including index or spot prices, location and quality differentials, as well as market supply and demand conditions. As a result, prices for natural gas and oil routinely fluctuate based on changes in these factors. Prices for gathering and treating services are generally fixed in nature but can vary due to the quality of the gas being treated. Each unit of production (barrel of crude oil and thousand cubic feet of natural gas) represents a separate performance obligation under the Company's contracts since each unit has economic benefit on its own and each is priced separately according to the terms of the contracts.

Comstock has elected to exclude all taxes from the measurement of transaction prices, and its revenues are reported net of royalties and exclude revenue interests owned by others because the Company acts as an agent when selling natural gas and oil, on behalf of royalty owners and working interest owners. Revenue is recorded in the month of production based on an estimate of the Company's share of volumes produced and prices realized. Gas services revenue is recorded in the month the services are performed and purchased gas is sold based on an estimate of natural gas volumes and contract prices. The Company recognizes any differences between estimates and actual amounts received in the month when payment is received. Historically, differences between estimated revenues and actual revenue received have not been significant. The amount of natural gas or oil sold may differ from the amount to which the Company is entitled based on its revenue interests in the properties. The Company did not have any significant imbalance positions at September 30, 2023 or December 31, 2022.

Credit Losses

Credit Losses

Substantially all of the Company's accounts receivable are due from either purchasers of natural gas and oil or participants in natural gas and oil wells for which the Company serves as the operator. Generally, operators of natural gas and oil wells have the right to offset future revenues against unpaid charges related to operated wells. Natural gas and oil sales are generally unsecured. Comstock assesses the collectability of its receivables based upon their age, the credit quality of the purchaser or participant and the potential for revenue offset. The Company has not had any significant credit losses in the past and believes its accounts receivable are fully collectible. Accordingly, no allowance for doubtful accounts has been recorded for the nine months ended September 30, 2023 and 2022.

Income Taxes

Income Taxes

Deferred income taxes are provided to reflect the future tax consequences or benefits of differences between the tax basis of assets and liabilities and their reported amounts in the financial statements using enacted tax rates.

In recording deferred income tax assets, the Company considers whether it is more likely than not that its deferred income tax assets will be realized in the future. The ultimate realization of deferred income tax assets is dependent upon the generation of future taxable income during the periods in which those deferred income tax assets would be deductible. The Company believes that after considering all the available objective evidence, historical and prospective, with greater weight given to historical evidence, management is not able to determine that it is more likely than not that all of its deferred tax assets will be realized. As a result, the Company established valuation allowances for its deferred tax assets and U.S. federal and state net operating loss carryforwards that are not expected to be utilized due to the uncertainty of generating taxable income prior to the expiration of the carryforward periods. The Company will continue to assess the valuation allowances against deferred tax assets considering all available information obtained in future periods.

The Company's federal income tax returns for the years subsequent to December 31, 2018 remain subject to examination. The Company's income tax returns in major state income tax jurisdictions remain subject to examination for various periods subsequent to December 31, 2019. The Company is currently under examination with the state of Louisiana and believes that its significant filing positions are highly certain and that all of its other significant income tax filing positions and deductions would be sustained under audit or the final resolution would not have a material effect on the consolidated financial statements. Therefore, the Company has not established any significant reserves for uncertain tax positions.

Fair Value Measurements

Fair Value Measurements

The Company holds or has held certain financial assets and liabilities that are required to be measured at fair value. These include cash and cash equivalents held in bank accounts and derivative financial instruments. Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants on the measurement date. A three-level hierarchy is followed for disclosure to show the extent and level of judgment used to estimate fair value measurements:

Level 1 — Inputs used to measure fair value are unadjusted quoted prices that are available in active markets for the identical assets or liabilities as of the reporting date.

Level 2 — Inputs used to measure fair value, other than quoted prices included in Level 1, are either directly or indirectly observable as of the reporting date through correlation with market data, including quoted prices for similar assets and liabilities in active markets and quoted prices in markets that are not active. Level 2 also includes assets and liabilities that are valued using models or other pricing methodologies that do not require significant judgment since the input assumptions used in the models, such as interest rates and volatility factors, are corroborated by readily observable data from actively quoted markets for substantially the full term of the financial instrument.

Level 3 — Inputs used to measure fair value are unobservable inputs that are supported by little or no market activity and reflect the use of significant management judgment. These values are generally determined using pricing models for which the assumptions utilize management's estimates of market participant assumptions.

Earnings Per Share

Earnings Per Share

Unvested restricted stock containing non-forfeitable rights to dividends are included in common stock outstanding and are considered to be participating securities and included in the computation of basic and diluted earnings per share pursuant to the two-class method. At September 30, 2023 and December 31, 2022, 1,430,949 and 966,058 shares of restricted stock, respectively, are included in common stock outstanding as such shares have a non-forfeitable right to participate in any dividends that might be declared and have the right to vote on matters submitted to the Company's stockholders.

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Tables)

9 Months Ended

Sep. 30, 2023

Accounting Policies [Abstract]

Schedule of Other Current Assets

Other current assets at September 30, 2023 and December 31, 2022 consisted of the following:

	As of
	September 30, 2023		December 31, 2022
	(In thousands)
Pipe and well equipment inventory	$	50,708	$	34,819
Production tax refunds receivable		14,988		11,156
Prepaid expenses		2,876		2,455
Prepaid drilling costs		—		4,265
Accrued proceeds from sale of natural gas and oil properties		—		3,118
Other		—		511
	$	68,572	$	56,324

Capitalized Exploratory Well Costs

The changes in capitalized exploratory well costs are as follows:

	Three Months Ended September 30,					Nine Months Ended September 30,
	2023			2022		2023			2022
	(In thousands)
Beginning capitalized exploratory well costs	$	34,196		$	9,771	$	867		$	6,966
Additions to exploratory well costs pending the determination of proved reserves		74,737			20,144		179,049			50,541
Determined to have found proved reserves		(71,838	)		—		(142,821	)		(27,592	)
Ending capitalized exploratory well costs	$	37,095		$	29,915	$	37,095		$	29,915

Summary of Lease Cost Recognized

Lease costs recognized during the three months and nine months ended September 30, 2023 and 2022 were as follows:

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
	(In thousands)
Operating lease cost included in general and administrative expense	$	445	$	436	$	1,334	$	1,307
Operating lease cost included in lease operating expense		523		370		1,533		970
Operating lease cost included in natural gas and oil properties		18,659		9,450		41,339		15,750
Variable lease cost (completion costs included in natural gas and oil properties)		25,970		11,730		31,032		22,857
Short-term lease cost (drilling rig costs included in natural gas and oil properties)		20,098		16,102		73,986		44,242
	$	65,695	$	38,088	$	149,224	$	85,126

Summary of Liabilities Under Contracts That Contain Operating Leases

As of September 30, 2023, expected future payments related to contracts that contain operating leases were as follows:

	(In thousands)
October 1 to December 31, 2023	$	15,291
2024		61,302
2025		58,919
2026		27,374
2027		17
Total lease payments		162,903
Imputed interest		(14,775	)
Total lease liability	$	148,128

Summary of Accrued Costs

Accrued costs at September 30, 2023 and December 31, 2022 consisted of the following:

	As of
	September 30, 2023		December 31, 2022
	(In thousands)
Accrued transportation costs	$	32,731	$	28,357
Accrued drilling costs		21,997		54,438
Accrued interest payable		19,730		54,867
Accrued income and other taxes		18,212		31,256
Accrued employee compensation		7,350		11,308
Accrued lease operating expenses		2,949		2,412
Other		697		473
	$	103,666	$	183,111

Summary of Changes in Total Estimated Asset Retirement Obligation Liability

The following table summarizes the changes in Comstock's total estimated liability for such obligations during the periods presented:

	Nine Months Ended September 30,
	2023			2022
	(In thousands)
Reserve for future abandonment costs at beginning of period	$	29,114		$	25,673
New wells placed on production		114			1,251
Acquisitions		—			1,211
Liabilities settled and assets disposed of		(42	)		(29	)
Accretion expense		1,248			1,129
Reserve for future abandonment costs at end of period	$	30,434		$	29,235

Schedule of Natural Gas Price Derivative

The Company had the following natural gas price derivative financial instruments at September 30, 2023:

	Future Production Period
	Three Months Ending December 31, 2023		Year Ending December 31, 2024		Total
Natural Gas Price Swap Contracts:
Volume (MMBtu)		—		91,500,000		91,500,000
Average Price per MMBtu			$	3.55	$	3.55
Natural Gas Price Collar Contracts:
Volume (MMBtu)		23,000,000				23,000,000
Average Price per MMBtu:
Average Ceiling	$	10.28			$	10.28
Average Floor	$	3.00			$	3.00

Schedule of Derivative Instruments

The classification of derivative financial instruments of assets or liabilities, consists of the following:

		As of
Type	Consolidated Balance Sheet Location	September 30, 2023		December 31, 2022
		(In thousands)
Asset Derivative Financial Instruments:
Natural gas price derivatives	Derivative Financial Instruments – current	$	23,973	$	23,884
		$	23,973	$	23,884
Liability Derivative Financial Instruments:
Natural gas price derivatives	Derivative Financial Instruments – current	$	—	$	4,420
		$	—	$	4,420
Natural gas price derivatives	Derivative Financial Instruments – long-term	$	4,540	$	—
		$	4,540	$	—

Schedule of Gains and Losses from Derivative Contracts

Gains and losses related to cash settlements and changes in the fair value recognized on the Company's derivative contracts recognized in the consolidated statement of operations were as follows:

	Three Months Ended September 30,					Nine Months Ended September 30,
Gain (Loss) on Derivatives Recognized in Earnings	2023		2022			2023		2022
	(In thousands)
Natural gas price derivatives	$	14,276	$	(271,335	)	$	76,190	$	(781,654	)
	$	14,276	$	(271,335	)	$	76,190	$	(781,654	)

Consolidated Income Tax Benefit (Provision)

The following is an analysis of the consolidated income tax provision (benefit):

	Three Months Ended September 30,					Nine Months Ended September 30,
	2023			2022		2023		2022
	(In thousands)
Current - Federal	$	—		$	10,001	$	—	$	11,400
Current - State		—			14,749		—		19,821
Deferred - Federal		3,999			66,732		28,350		124,600
Deferred - State		(391	)		11,328		528		23,789
	$	3,608		$	102,810	$	28,878	$	179,610

Difference Between Federal Statutory Rate and Effective Tax Rate

The difference between the federal statutory rate of 21% and the effective tax rate is due to the following:

	Three Months Ended September 30,						Nine Months Ended September 30,
	2023			2022			2023			2022
Tax at statutory rate		21.0	%		21.0	%		21.0	%		21.0	%
Tax effect of:
Valuation allowance on deferred tax assets		5.5			(4.1	)		1.7			(4.0	)
State income taxes, net of federal benefit		(8.2	)		5.8			(1.6	)		5.6
Nondeductible stock-based compensation		1.7			(0.2	)		0.8			(0.1	)
Other		(0.3	)		(0.1	)		(0.1	)		—
Effective tax rate		19.7	%		22.4	%		21.8	%		22.5	%

Summary of Carrying Amounts and Fair Values of Financial Instruments

The following presents the carrying amounts and the fair values of the Company's financial instruments as of September 30, 2023 and December 31, 2022:

	As of
	September 30, 2023				December 31, 2022
	Carrying Value		Fair Value		Carrying Value		Fair Value
	(In thousands)
Assets:
Commodity-based derivatives (1)	$	23,973	$	23,973	$	23,884	$	23,884
Liabilities:
Commodity-based derivatives (1)	$	4,540	$	4,540	$	4,420	$	4,420
Bank credit facility (2)	$	345,000	$	345,000	$	—	$	—
6.75% senior notes due 2029 (3)	$	1,229,230	$	1,116,791	$	1,229,836	$	1,129,029
5.875% senior notes due 2030 (3)	$	965,000	$	829,900	$	965,000	$	846,788

(1)The Company's commodity-based derivatives are classified as Level 2 and measured at fair value using third party pricing services and other active markets or broker quotes that are readily available in the public markets.

(2)The carrying value of our floating rate debt outstanding approximates fair value.

(3)The fair value of the Company's fixed rate debt was based on quoted prices as of September 30, 2023 and December 31, 2022, respectively, a Level 1 measurement.

Weighted Average Shares of Unvested Restricted Stock

Weighted average shares of unvested restricted stock outstanding were as follows:

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
	(In thousands)
Unvested restricted stock		1,469		890		1,186		914

Common Stock and Convertible Stock Dilutive in Weighted average unearned PSUs outstanding

The treasury stock method is used to measure the dilutive effect of PSUs.

Weighted average unearned PSUs outstanding were as follows:

	Three Months Ended September 30,				Nine Months Ended September 30,
	2023		2022		2023		2022
	(In thousands, except per unit amounts)
Weighted average PSUs		744		942		631		1,024
Weighted average grant date fair value per unit	$	15.92	$	14.52	$	15.92	$	14.52

Schedule of Basic and Diluted Income (Loss) Per Share

Basic and diluted income (loss) per share for the three months and nine months ended September 30, 2023 and 2022 were determined as follows:

	Three Months Ended September 30,
	2023						2022
	Income		Shares		Per Share		Loss			Shares		Per Share
	(In thousands, except per share amounts)
Net income attributable to common stock	$	14,720					$	351,185
Income allocable to unvested restricted shares		—						(1,339	)
Basic income attributable to common stock		14,720		276,999	$	0.05		349,846			232,482	$	1.50
Effect of Dilutive Securities:
Restricted stock		—		—				1,339			392
Performance stock units		—		—				—			1,091
Convertible preferred stock		—		—				4,411			43,750
Diluted income attributable to common stock	$	14,720		276,999	$	0.05	$	355,596			277,715	$	1.28

	Nine Months Ended September 30,
	2023						2022
	Income		Shares		Per Share		Loss			Shares		Per Share
	(In thousands, except per share amounts)
Net income attributable to common stock	$	103,517					$	607,974
Income allocable to unvested restricted shares		—						(2,384	)
Basic income attributable to common stock		103,517		276,741	$	0.37		605,590			232,170	$	2.61
Effect of Dilutive Securities:
Restricted stock		—		—				2,384			541
Performance stock units		—		—				—			1,144
Convertible preferred stock		—		—				13,089			43,750
Diluted income attributable to common stock	$	103,517		276,741	$	0.37	$	621,063			277,605	$	2.24

Cash Payments Made for Interest and Income Taxes

Cash payments made for interest and income taxes and other non-cash investing activities for the nine months ended September 30, 2023 and 2022, respectively, were as follows:

	Nine Months Ended September 30,
	2023			2022
	(In thousands)
Cash payments for:
Interest payments	$	150,239		$	164,106
Income tax payments	$	29,796		$	719
Non-cash investing activities include:
Increase (decrease) in accrued capital expenditures	$	(32,441	)	$	16,202
Liabilities assumed in exchange for right-of-use lease assets	$	157,789		$	109,546

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LONG-TERM DEBT (Tables)

9 Months Ended

Sep. 30, 2023

Debt Disclosure [Abstract]

Long-term Debt

At September 30, 2023, long-term debt was comprised of the following:

	(In thousands)
6.75% Senior Notes due 2029:
Principal	$	1,223,880
Premium, net of amortization		5,350
5.875% Senior Notes due 2030:
Principal		965,000
Bank Credit Facility:
Principal		345,000
Debt issuance costs, net of amortization		(35,823	)
	$	2,503,407

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Other Current Assets (Details) - USD ($) $ in Thousands	Sep. 30, 2023	Dec. 31, 2022
Accounting Policies [Abstract]
Pipe and well equipment inventory	$ 50,708	$ 34,819
Production tax refunds receivable	14,988	11,156
Prepaid expenses	2,876	2,455
Prepaid drilling costs	0	4,265
Accrued proceeds from sale of natural gas and oil properties	0	3,118
Other	0	511
Other current assets	$ 68,572	$ 56,324

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Property, Equipment and Goodwill (Detail) - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022	Dec. 31, 2022
Increase (Decrease) in Capitalized Exploratory Well Costs that are Pending Determination of Proved Reserves [Roll Forward]
Beginning capitalized exploratory well costs	$ 34,196,000	$ 9,771,000	$ 867,000	$ 6,966,000
Additions to exploratory well costs pending the determination of proved reserves	74,737,000	20,144,000	179,049,000	50,541,000
Determined to have found proved reserves	(71,838,000)	0	(142,821,000)	(27,592,000)
Ending capitalized exploratory well costs	37,095,000	$ 29,915,000	37,095,000	$ 29,915,000
Impairment of oil and gas properties			0
Goodwill	$ 335,897,000		$ 335,897,000		$ 335,897,000

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Leases (Detail) $ in Thousands		3 Months Ended		9 Months Ended
	Apr. 01, 2022 Contract	Sep. 30, 2023 USD ($)	Sep. 30, 2022 USD ($)	Sep. 30, 2023 USD ($) Contract	Sep. 30, 2022 USD ($)	Dec. 31, 2022 USD ($)
Lessee, Lease, Description [Line Items]
Operating lease, right-of-use assets		$ 148,066		$ 148,066		$ 90,716
Prior advance notice period for cancellation of rig contracts				45 days
Cash payments for operating leases associated with right-of-use assets		1,000	$ 800	$ 2,900	$ 2,300
Cash payments for operating leases associated with ROU assets used for investing activities		$ 64,700	$ 37,300	$ 146,400	$ 82,800
Operating lease, weighted average remaining lease term		2 years 7 months 6 days		2 years 7 months 6 days		2 years 2 months 12 days
Operating lease, weighted average discount rate, percent		6.90%		6.90%		3.50%
Expected future payments for short term leased drilling services		$ 7,000		$ 7,000
Hydraulic Fracturing Fleet Contract
Lessee, Lease, Description [Line Items]
Operating lease, term of contract	3 years
Operating lease, number of contract | Contract	1
Drilling Rig Contract
Lessee, Lease, Description [Line Items]
Operating lease, term of contract		3 years		3 years
Operating lease, number of contract | Contract				1

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Summary of Lease Cost Recognized (Detail) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Operations And Summary Of Significant Accounting Policies [Line Items]
Operating lease cost	$ 65,695	$ 38,088	$ 149,224	$ 85,126
Operating lease cost included in general and administrative expense
Operations And Summary Of Significant Accounting Policies [Line Items]
Operating lease cost	445	436	1,334	1,307
Operating lease cost included in lease operating expense
Operations And Summary Of Significant Accounting Policies [Line Items]
Operating lease cost	523	370	1,533	970
Operating lease cost included in natural gas and oil properties
Operations And Summary Of Significant Accounting Policies [Line Items]
Operating lease cost	18,659	9,450	41,339	15,750
Variable lease cost completion costs included in natural gas and oil properties
Operations And Summary Of Significant Accounting Policies [Line Items]
Variable lease cost	25,970	11,730	31,032	22,857
Short term lease cost drilling rig costs included in natural gas and oil properties
Operations And Summary Of Significant Accounting Policies [Line Items]
Operating lease cost	$ 20,098	$ 16,102	$ 73,986	$ 44,242

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Summary of Liabilities Under Contract Contain Operating Leases (Detail) $ in Thousands	Sep. 30, 2023 USD ($)
Accounting Policies [Abstract]
October 1 to December 31, 2023	$ 15,291
2024	61,302
2025	58,919
2026	27,374
2027	17
Total lease payments	162,903
Imputed interest	(14,775)
Total lease liability	$ 148,128

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Summary of Accrued Costs (Detail) - USD ($) $ in Thousands	Sep. 30, 2023	Dec. 31, 2022
Accounting Policies [Abstract]
Accrued transportation costs	$ 32,731	$ 28,357
Accrued drilling costs	21,997	54,438
Accrued interest payable	19,730	54,867
Accrued income and other taxes	18,212	31,256
Accrued employee compensation	7,350	11,308
Accrued lease operating expenses	2,949	2,412
Other	697	473
Total accrued expenses	$ 103,666	$ 183,111

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Summary of Changes in Reserve for Future Abandonment Costs (Detail) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Reserve for future abandonment costs at beginning of period	$ 29,114	$ 25,673
New wells placed on production	114	1,251
Acquisitions	0	1,211
Liabilities settled and assets disposed of	(42)	(29)
Accretion expense	1,248	1,129
Reserve for future abandonment costs at end of period	$ 30,434	$ 29,235

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Derivatives Narrative (Detail)		9 Months Ended
	Nov. 02, 2023 MMBTU $ / Mcf	Sep. 30, 2023 USD ($) MMBTU $ / Mcf
Derivative [Line Items]
Cash flow hedges derivative instruments | $		$ 0
Natural Gas Swap Contracts
Derivative [Line Items]
Volume (in MMBTU) | MMBTU		91,500,000
Average price (in dollars per MMBtu) | $ / Mcf		3.55
Natural Gas Swap Contracts | Subsequent Event
Derivative [Line Items]
Volume (in MMBTU) | MMBTU	47,580,000
Average price (in dollars per MMBtu) | $ / Mcf	3.56

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Schedule of Derivative Contracts Volume and Prices (Detail)	9 Months Ended
	Sep. 30, 2023 MMBTU $ / Mcf
Natural Gas Price Swap Contracts:
Derivative [Line Items]
Volume (in MMBTU) | MMBTU	91,500,000
Average price (in dollars per MMBtu)	3.55
Natural Gas Price Swap Contracts: | Swap Contracts for 2023
Derivative [Line Items]
Volume (in MMBTU) | MMBTU	0
Natural Gas Price Swap Contracts: | Swap Contracts for 2024
Derivative [Line Items]
Volume (in MMBTU) | MMBTU	91,500,000
Average price (in dollars per MMBtu)	3.55
Natural Gas Price Collar Contracts:
Derivative [Line Items]
Volume (in MMBTU) | MMBTU	23,000,000
Average ceiling (dollars per unit)	10.28
Average floor (dollars per unit)	3
Natural Gas Price Collar Contracts: | Collar Contracts for 2023
Derivative [Line Items]
Volume (in MMBTU) | MMBTU	23,000,000
Average ceiling (dollars per unit)	10.28
Average floor (dollars per unit)	3

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Schedule of Derivative Instruments (Detail) - USD ($) $ in Thousands	Sep. 30, 2023	Dec. 31, 2022
Asset Derivative Financial Instruments:
Derivative Financial Instruments - Current Asset	$ 23,973	$ 23,884
Liability Derivative Financial Instruments:
Derivative Financial Instruments - Current Liability	0	4,420
Derivative Financial Instruments - Long Term Liability	4,540	0
Natural Gas Price Derivatives - Derivative Financial Instruments - Current Asset
Asset Derivative Financial Instruments:
Derivative Financial Instruments - Current Asset	23,973	23,884
Natural Gas Price Derivatives - Derivative Financial Instruments - Current Liability
Liability Derivative Financial Instruments:
Derivative Financial Instruments - Current Liability	0	4,420
Natural Gas Price Derivatives - Derivative Financial Instruments - Long Term Liability
Liability Derivative Financial Instruments:
Derivative Financial Instruments - Long Term Liability	$ 4,540	$ 0

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Schedule of Gains and Losses from Derivative Financial Instruments (Detail) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Derivative [Line Items]
Gain (Loss) on Derivatives Recognized in Earnings	$ 14,276	$ (271,335)	$ 76,190	$ (781,654)
Natural gas price derivatives
Derivative [Line Items]
Gain (Loss) on Derivatives Recognized in Earnings	$ 14,276	$ (271,335)	$ 76,190	$ (781,654)

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Share Based Compensation (Details) - USD ($) $ / shares in Units, $ in Thousands	1 Months Ended	3 Months Ended		9 Months Ended
	Jun. 30, 2023	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022	Dec. 31, 2022
Net income (loss) attributable to common stock
Stock-based compensation				$ 7,006	$ 4,918
Restricted Stock
Net income (loss) attributable to common stock
Granted (in shares)	954,031
Value per share (in dollars per share)	$ 9.8
Shares of unvested restricted stock outstanding (in shares)		1,430,949		1,430,949		966,058
Weighted average grant date fair value of stock grants per share (in dollars per share)		$ 11.62		$ 11.62
Unrecognized compensation cost related to unvested restricted stock		$ 14,300		$ 14,300
Period in which compensation cost expected to be recognized				2 years 2 months 12 days
PSUs
Net income (loss) attributable to common stock
Period in which compensation cost expected to be recognized				2 years 3 months 18 days
Number of Performance Shares Units Awards Granted	359,689
Grant Date Fair Value Of Performance Share Units	$ 13.64
Number of performance stock units ("PSUs") outstanding (in shares)		750,399		750,399
Weighted average grant date fair value of PSUs per unit (in dollars per share)		$ 15.92		$ 15.92
Minimum final number of shares of common stock issuable based on performance multiplier (in shares)				0
Maximum final number of shares of common stock issuable based on performance multiplier (in shares)				1,500,798
Unrecognized expense, performance share units				$ 7,900
General and Administrative Expense
Net income (loss) attributable to common stock
Stock-based compensation		$ 2,700	$ 1,800	$ 7,000	$ 4,900

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Revenue Recognized (Details)	9 Months Ended
	Sep. 30, 2023 USD ($) Product	Dec. 31, 2022 USD ($)	Sep. 30, 2022 USD ($)
Accounting Policies [Abstract]
Number of primary products | Product	2
Contract cash settlement max days	25 days
Contract cancellable notice term	30 days
Natural gas and oil sales and gas services	$ 157,130,000	$ 415,079,000
Allowance for doubtful accounts	$ 0		$ 0

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Consolidated Income Tax Provision (Detail) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Accounting Policies [Abstract]
Current - Federal	$ 0	$ 10,001	$ 0	$ 11,400
Current - State	0	14,749	0	19,821
Deferred - Federal	3,999	66,732	28,350	124,600
Deferred - State	(391)	11,328	528	23,789
Total	$ 3,608	$ 102,810	$ 28,878	$ 179,610

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Difference Between Federal Statutory Rate and Effective Tax Rate (Detail)	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Accounting Policies [Abstract]
Tax at statutory rate	21.00%	21.00%	21.00%	21.00%
Tax effect of:
Valuation allowance on deferred tax assets	5.50%	(4.10%)	1.70%	(4.00%)
State income taxes, net of federal benefit	(8.20%)	5.80%	(1.60%)	5.60%
Nondeductible stock-based compensation	1.70%	(0.20%)	0.80%	(0.10%)
Other	(0.30%)	(0.10%)	(0.10%)	0.00%
Effective tax rate	19.70%	22.40%	21.80%	22.50%

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Summary of Carrying Amounts and Fair Values of Financial Instruments (Detail) - USD ($) $ in Thousands	Sep. 30, 2023	Dec. 31, 2022	Sep. 30, 2022
Financial Instruments, Financial Assets, Balance Sheet Groupings [Abstract]
Derivative financial instruments	$ 23,973	$ 23,884
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Derivative financial instruments	0	4,420
Bank Credit Facility:
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt, carrying value	345,000	0
Long-term debt, fair value	$ 345,000	0
6.75% Senior Notes due 2029:
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Interest rate on debt instrument	6.75%		6.75%
5.875% Senior Notes due 2030:
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Interest rate on debt instrument	5.875%
Level 2 and Level 3
Financial Instruments, Financial Assets, Balance Sheet Groupings [Abstract]
Derivative financial instruments	$ 23,973	23,884
Derivative financial asset, fair value	23,973	23,884
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Derivative financial instruments	4,540	4,420
Derivative financial liabilities, fair value	4,540	4,420
Level 1 | 6.75% Senior Notes due 2029:
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt, carrying value	1,229,230	1,229,836
Long-term debt, fair value	1,116,791	1,129,029
Level 1 | 5.875% Senior Notes due 2030:
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term debt, carrying value	965,000	965,000
Long-term debt, fair value	$ 829,900	$ 846,788

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Earnings Per Share (Detail) - shares	9 Months Ended
	Sep. 30, 2023	Dec. 31, 2022
Operations And Summary Of Significant Accounting Policies [Line Items]
Performance multiplier, minimum	0.00%
Performance multiplier, maximum	200.00%
Participating securities that share in losses (in shares)	0
Restricted Stock
Operations And Summary Of Significant Accounting Policies [Line Items]
Shares of unvested restricted stock outstanding (in shares)	1,430,949	966,058

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Weighted Average Shares of Unvested Restricted Stock (Detail) - shares shares in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Accounting Policies [Abstract]
Unvested restricted stock (in shares)	1,469	890	1,186	914

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Common Stock and Convertible Stock Dilutive in Weighted average unearned PSUs outstanding (Detail) - $ / shares shares in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Accounting Policies [Abstract]
Weighted average PSUs (in shares)	744	942	631	1,024
Weighted average grant date fair value per unit (in dollars per share)	$ 15.92	$ 14.52	$ 15.92	$ 14.52

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Basic and Diluted Income (Loss) Per Share (Detail) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Net income (loss) attributable to common stock
Net income attributable to common stock	$ 14,720	$ 351,185	$ 103,517	$ 607,974
Income allocable to unvested restricted shares	0	(1,339)	0	(2,384)
Basic income attributable to common stock	$ 14,720	$ 349,846	$ 103,517	$ 605,590
Basic income attributable to common stock (in shares)	276,999	232,482	276,741	232,170
Basic income attributable to common stock (in dollars per share)	$ 0.05	$ 1.5	$ 0.37	$ 2.61
Effect of Dilutive Securities:
Dilutive securities, effect on basic earnings per share, options and restrictive stock units	$ 0	$ 4,411	$ 0	$ 13,089
Convertible preferred stock (in shares)	0	43,750	0	43,750
Diluted income attributable to common stock	$ 14,720	$ 355,596	$ 103,517	$ 621,063
Diluted income attributable to common stock (in shares)	276,999	277,715	276,741	277,605
Diluted income attributable to common stock (in dollars per share)	$ 0.05	$ 1.28	$ 0.37	$ 2.24
Restricted Stock
Effect of Dilutive Securities:
Dilutive securities, effect on basic earnings per share, options and restrictive stock units	$ 0	$ 1,339	$ 0	$ 2,384
Dilutive effect of share-based payment arrangements (in shares)	0	392	0	541
PSUs
Effect of Dilutive Securities:
Dilutive securities, effect on basic earnings per share, options and restrictive stock units	$ 0	$ 0	$ 0	$ 0
Dilutive effect of share-based payment arrangements (in shares)	0	1,091	0	1,144

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES - Supplementary Information of Consolidated Statements of Cash Flows (Detail) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022
Cash payments for:
Interest payments	$ 150,239	$ 164,106
Income tax payments	29,796	719
Non-cash investing activities include:
Increase (decrease) in accrued capital expenditures	(32,441)	16,202
Liabilities assumed in exchange for right-of-use lease assets	$ 157,789	$ 109,546

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LONG-TERM DEBT - Long-term Debt (Detail) - USD ($) $ in Thousands	Sep. 30, 2023	Dec. 31, 2022	Sep. 30, 2022
Debt Instrument [Line Items]
Debt issuance costs, net of amortization	$ (35,823)
Long-term debt	2,503,407	$ 2,152,571
Bank Credit Facility:
Debt Instrument [Line Items]
Principal	345,000
6.75% Senior Notes due 2029:
Debt Instrument [Line Items]
Principal	1,223,880
Premium, net of amortization	$ 5,350
Interest rate on debt instrument	6.75%		6.75%
5.875% Senior Notes due 2030:
Debt Instrument [Line Items]
Principal	$ 965,000
Interest rate on debt instrument	5.875%

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LONG-TERM DEBT - Additional Information (Detail) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Debt Instrument [Line Items]
Loss on early retirement of debt	$ 0	$ 0	$ 0	$ 46,840
7.5% Senior Notes due 2025
Debt Instrument [Line Items]
Interest rate on debt instrument		7.50%		7.50%
Redemption price				$ 258,100
6.75% Senior Notes due 2029:
Debt Instrument [Line Items]
Principal	$ 1,223,880		$ 1,223,880
Interest rate on debt instrument	6.75%	6.75%	6.75%	6.75%
Repurchased face amount		$ 26,100		$ 26,100
Repurchase amount		$ 24,900		$ 24,900
Bank Credit Facility
Debt Instrument [Line Items]
Principal	$ 345,000		$ 345,000
Bank credit facility	1,500,000		$ 1,500,000
Leverage ratio			350.00%
Current ratio			100.00%
Bank Credit Facility | Minimum
Debt Instrument [Line Items]
Commitment fee on unused borrowing base			0.375%
Bank Credit Facility | Maximum
Debt Instrument [Line Items]
Commitment fee on unused borrowing base			0.50%
Bank Credit Facility | Secured Overnight Financing Rate (SOFR) | Minimum
Debt Instrument [Line Items]
Spread rate for interest rate on credit facility			1.75%
Bank Credit Facility | Secured Overnight Financing Rate (SOFR) | Maximum
Debt Instrument [Line Items]
Spread rate for interest rate on credit facility			2.75%
Bank Credit Facility | Base Rate | Minimum
Debt Instrument [Line Items]
Spread rate for interest rate on credit facility			0.75%
Bank Credit Facility | Base Rate | Maximum
Debt Instrument [Line Items]
Spread rate for interest rate on credit facility			1.75%
Revolving Credit Facility | Wells Fargo Credit Facility
Debt Instrument [Line Items]
Bank credit facility	$ 2,000,000		$ 2,000,000

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COMMITMENTS AND CONTINGENCIES (Detail) $ in Millions	12 Months Ended
	Dec. 31, 2022 Drillingrig	Jul. 31, 2022 USD ($)
Completion Service Contracts
Other Commitments [Line Items]
Other commitment, period	3 years
Drilling Rig Contracts
Other Commitments [Line Items]
Other commitment number of drilling rigs new | Drillingrig	3
Drilling Rig Contracts | Minimum
Other Commitments [Line Items]
Other commitment, to be paid, year one		$ 12.2
Other commitment, to be paid, year two		12.2
Other commitment, to be paid, year three		$ 12.2

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RELATED PARTY TRANSACTIONS (Detail) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2023 USD ($)	Sep. 30, 2022 USD ($)	Sep. 30, 2023 USD ($) $ / Mcf	Sep. 30, 2022 USD ($)	Dec. 31, 2022 USD ($)
Related Party Transaction [Line Items]
Revenues	$ 376,737	$ 1,190,005	$ 1,154,526	$ 2,705,673
From affiliates	21,168		$ 21,168		$ 18,527
Partnerships owned by majority stockholder
Related Party Transaction [Line Items]
Related party revenue, fee (in USD per Mcf) | $ / Mcf			0.02
From affiliates	21,200		$ 21,200		$ 18,500
Partnerships owned by majority stockholder | Partnership costs to drill and operating wells and overhead fees
Related Party Transaction [Line Items]
Revenues	$ 327	$ 152	$ 1,000	$ 735

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SUBSEQUENT EVENT (Details) - USD ($) $ / shares in Units, $ in Millions		3 Months Ended		9 Months Ended
	Oct. 31, 2023	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022	Oct. 01, 2023
Subsequent Event [Line Items]
Common stock dividends declared (in dollars per share)		$ 0.125	$ 0	$ 0.375	$ 0
Subsequent Event
Subsequent Event [Line Items]
Common stock dividends declared (in dollars per share)	$ 0.125
Subsequent Event | Midstream Partnership | Quantum Capital Solutions
Subsequent Event [Line Items]
Total capital commitment						$ 300